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195-198
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251016 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 2-36 50029220140000 190024 9/17/2025 BAKER SPN T40994 END 2-74 50029237850000 224024 9/22/2025 HALLIBURTON PATCH T40995 KU 12-17 50133205770000 208089 9/23/2025 YELLOWJACKET TEMP-CALIPER T40996 KU 24-7RD 50133203520100 205099 9/24/2025 YELLOWJACKET TEMP-CALIPER T40997 M-25 50733203910000 187086 8/31/2025 YELLOWJACKET CALIPER T40998 MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey T40999 MPF-61 50029225820000 195117 9/27/2025 READ CaliperSurvey T41000 MPU H-16 50029232270000 204190 10/6/2025 HALLIBURTON COILFLAG T41001 NIK SI17-SE2 50629235120000 214041 9/23/2025 HALLIBURTON IPROF T41002 NS-19 50029231220000 202207 9/8/2025 HALLIBURTON COILFLAG T41003 NS-19 50029231220000 202207 9/15/2025 HALLIBURTON COILFLAG T41003 ODSN-26 50703206420000 211121 10/7/2025 HALLIBURTON MFC24 T41004 PBU 01-25A 50029208740100 225056 9/13/2025 BAKER MRPM T41005 PBU 01-25A 50029208740100 225056 9/13/2025 HALLIBURTON RBT-COILFLAG T41005 PBU 01-31A 50029216260100 225070 9/22/2025 BAKER MRPM T41006 PBU 01-31A 50029216260100 225070 9/23/2025 HALLIBURTON RBT-COILFLAG T41006 PBU 05-09A 50029202540100 199014 9/18/2025 READ ArcherVIVID T41007 PBU 07-16A 50029208560100 201153 9/20/2025 HALLIBURTON RBT T41008 PBU 07-23C 50029216350300 225043 7/4/2025 BAKER MRPM T41009 PBU 13-24B 50029207390200 224087 9/18/2025 HALLIBURTON RBT T41010 PBU 15-11C 50029206530300 210163 9/6/2025 HALLIBURTON RBT T41011 PBU 15-49C 50029226510300 215129 9/10/2025 HALLIBURTON RBT T41012 PBU H-07B 50029202420200 225064 9/30/2025 HALLIBURTON RBT-COILFLAG T41013 PBU P19 L1 50029220946000 212056 10/3/2025 HALLIBURTON RBT T41014 PBU S-14A 50029208040100 204071 9/25/2025 HALLIBURTON RBT T41015 PBU V-105 50029230970000 202131 9/30/2025 HALLIBURTON RMT3D T41016 Please include current contact information if different from above. MPC-22A 50029224890100 195198 10/4/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.10.20 13:17:06 -08'00' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________MILNE PT UNIT C-22A JBR 11/25/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:0 Tj Used 2-7/8" and 4.5" 12 Accumulator bottles pre charge average 1004 psi Test Results TEST DATA Rig Rep:C. Pace/ M. SamOperator:Hilcorp Alaska, LLC Operator Rep:A. Haberthur/ M. Heinz-Bro Rig Owner/Rig No.:Hilcorp ASR 1 PTD#:1951980 DATE:10/10/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopKPS251010125840 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 4.5 MASP: 2823 Sundry No: 325-569 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 1 P Lower Kelly 0 NA Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 16 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 11"P #1 Rams 1 2-7/8" x 5" V P #2 Rams 1 2-7/8" x 5" V P #3 Rams 1 Blinds P #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2-1/16'P HCR Valves 1 2-1/16'P Kill Line Valves 3 2-1/16'P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1750 200 PSI Attained P20 Full Pressure Attained P66 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P4 @ 2306 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P13 #1 Rams P6 #2 Rams P6 #3 Rams P7 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ESP Swap 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 9,995'9,751' Casing Collapse Conductor 520psi Surface 3,090psi Production 5,410psi Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Hayden Moser Contact Email:Hayden.Moser@hilcorp.com Contact Phone:907-793-1231 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 2,823 N/A Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT C-22A MILNE POINT Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 10/15/2025 Subsequent Form Required: Suspension Expiration Date: 195-198 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22489-01-00 Hilcorp Alaska LLC C.O. 816 TVD Burst 6,715' 8,435' Length AOGCC USE ONLY 6.5# / L-80 / EUE 8rd 7,739'2-7/8" MD 1,530psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0047437 7,254' 9,751' 7,073' 5,750psi 7,240psi 4,756' 5,847' Size Proposed Pools: 112' 112' KUPARUK RIVER OIL N/A 80' 20" 9-5/8" 7" 6,686' 4-1/2"1,729' 8,408' ZXP Liner Top Packer and N/A 8,266' MD / 5,723' TVD and N/A Perforation Depth MD (ft): 9,995' See Schematic See Schematic 8,430psi7,254' Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:39 am, Sep 19, 2025 325-569 DSR-9/24/25 10-404 MGR24SEP2025 * BOPE pressure test to 3500 psi. Annular to 2500 psi. 24 hour notice. A.Dewhurst 02OCT25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.10.03 09:22:49 -08'00'10/03/25 RBDMS JSB 100625 Well: MPC-22 PTD: 195-198 API: 50-029-22489-01-00 Well Name:MPC-22 API Number:50-029-22489-01-00 Current Status:Shut-in Producer Rig:ASR #1 Estimated Start Date:10/15/2025 Estimated Duration:7days Regulatory Contact:Tom Fouts Permit to Drill Number:195-198 First Call Engineer:Hayden Moser (479) 899-8940 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 3513 psig @ 6,896’ TVD 8/10/2025 |9.8 PPGE Max Potential Surface Pressure: 2,823 psi Gas Column Gradient (0.1 psi/ft) Max Angle: 55° Inclination at 2,793’ MD Brief Well Summary: MPU C-22 was drilled and completed in December 1994 as a Kuparuk River formation producer. The ESP failed in February 1995 and the RWO was unable to retrieve the stuck pump. The well was then sidetracked and fracture stimulated in December 1995. C-22A had multiple ESPs installed (January 1996 (initial), August 1998 and October 1998) before the well was converted to gas lift in September 2002 due to high GOR and gas slugs. The well was converted back to ESP lift in March 2011. One ESP swap has occurred since then in July of 2016. Currently the well is grounded out after 9 years of runtime. Objectives: Pull failed ESP completion, run new ESP completion with packer. Notes Regarding Wellbore Condition: - 7” casing CMIT TxIA test to 1,000 psi passed on 2/21/2011 at 8,240’ MD. - Well requires a casing test during RWO. - Well requires a packer because reservoir pressure is greater than 8.55 PPGE. Pre-Rig Procedure (Non Sundried Work) Slickline 1. RU slickline, pressure test PCE to 250psi low / 3,500psi high. 2. Drift and tag with sample bailer. 3. Caliper from ~7,679’ MD to surface. 4. RIH for SBHPS with 10 min stops at ~7,632’ & ~7,310’ MD. 5. Attempt to pull dummy valve from GLM at 7,523’ MD and leave open. 6. Pull DPSOV and set dummy valve in GLM at 143’ MD. 7. RDMO. Pumping & Well Support 1. Clear and level pad area in front of well. Spot rig mats and containment. 2. RD well house and flowlines. Clear and level area around well. 3. RU Little Red Services. RU reverse out skid and 500 barrel returns tank. 4. Pressure test lines to 3,500 psi. 5. Circulate at least one wellbore volume with 10.0# brine water down tubing, taking returns up casing to 500 barrel returns tank. Bullhead down tbg and IA taking returns to formation as needed to establish and maintain a full column of 10.0# brine. Well: MPC-22 PTD: 195-198 API: 50-029-22489-01-00 6. Confirm well is dead. Contact operations engineer if freeze protection is needed prior to ASR arrival. 7. RD Little Red Services and reverse out skid. 8. Set BPV. ND tree. NU BOPE. RWO Procedure (Begin Sundried Work) 1. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment, and lines to 500 barrel returns tank. 2. Check for pressure and if 0 psi set CTS plug. If needed, bleed off any residual pressure off tubing and casing. a. If needed, kill well with produced water prior to setting CTS. 3. Test BOPE to 250 psi low/ 3,500 psi high. Test annular to 250 psi low/ 3,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry conditions of approval. d. Test VBR rams on 2-7/8” & 4-½” test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Bleed any pressure on casing to the returns tank. Pull CTS plug. Bleed any pressure off tubing to the returns tank. Kill well with 10.0# brine water as needed. Pull BPV. a. If indications show pressure underneath BPV, lubricate out BPV. 5. Call out ESP rep for ESP pull. 6. RU spoolers to handle ESP cable. 7. MU landing joint or spear, BOLDS, PU on the tubing hanger. a. Tubing hanger is an FMC 11” x 2-7/8”, with 2-7/8” EUE thread. b. 2016 tubing PU weight on ASR #1 recorded as 102k#. Slack off weight recorded as 79k#. c. 2-7/8” L-80 EUE yield is 145k#. 8. Confirm hanger free, lay down tubing hanger. 9. POOH and lay down the 2-7/8” tubing per the tubing caliper. a. Confirm with Engineer which tubing to keep based on Caliper data. b. Keep ported discharge head and centralizer for future use. c. Note any sand or scale inside or on the outside of the ESP on the morning report. d. Recorded Clamp Totals: i. Canon Clamps: 128 ii. SS Bands = 1 – 1-¼” on the motor iii. Protectolizers = 5 iv. Flatguards clamps = 2 10. Lay Down ESP. Slickline 11. RU slickline, pressure test PCE to 250psi low / 3,500psi high. 12. Drift and tag with 3.75” gauge ring to PBTD. Well: MPC-22 PTD: 195-198 API: 50-029-22489-01-00 13. RD slickline. E-line 14. RU E-line, pressure test PCE to 250psi low / 3,500psi high. 15. Perforate B-Silts 9424’-9489’ & 9510’-9564’ (119’ total). Correlation log to be provided at a later date. 16. RD E-line. Slickline 17. RU slickline, pressure test PCE to 250psi low / 3,500psi high. 18. Drift and tag with 3.75” gauge ring to PBTD. 19. Drift and tag with 6.15” gauge ring to TOL @ 8,266’ MD. 20. ***Contingency*** If clear to TOL, run 7” slickline retrievable bridge plug to ~8225’. 21. ***Contingency*** MIT-IA 7” casing to 1,500 psig for 30 minutes. 22. ***Contingency*** Retrieve 7” WLRBP. 23. RD slickline. ***Contingency*** RWO Steps 24. If either slickline gauge ring tags indicate fill/obstructions. PU 3-1/2” workstring and cleanout BHA. 25. Cleanout well to +-9850’. 26. POOH while filling hole with 2x displacement. 27. Make a dedicated cleanout run for the 7” csg to the TOL @ 8,266’ MD if necessary. 28. PU and RIH with 7” test packer to ~8,225’ MD. 29. MIT-IA 7” casing to 1,500 psig for 30 minutes. 30. POOH with test packer. RWO 31. RIH with new and used 2-7/8” 6.5# L-80 ESP completion to +/- 7,736’ and obtain string weights. a. Check electrical continuity every 1000’. b. Note PU and SO weights on tally. c. Install ESP clamps per ESP rep, and cross coupling clamps every other joint d. Photograph vent packer prior to running in hole. 32. PU and MU packer with Vent Valves. Verify that there are six (6) setting shear pins and confirm with OE number of release shear pins. Confirm with OE on overpull target to release pins to shear. Nom. (OD)Length Item Lb/ft Material Notes 5.85 XX Centralizer XX ~7,736’ MD 4.5 XX Intake Sensor XX 5.62 XX Motor XX 5.13 XX Lower Tandem Seal XX 5.13 XX Upper Tandem Seal XX 5.38 XX Gas Separator XX Well: MPC-22 PTD: 195-198 API: 50-029-22489-01-00 5.38 XX GINPSH XX 5.38 XX Pump XX XX Ported Discharge Head XX L-80 2-7/8" 10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 30 2-7/8" EUE 8rd L-80 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” XN-nipple 2.313" / 2.205" No-Go 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 60 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~5,344 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"2 2-7/8” X-nipple with RHC profile 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 31 2-7/8" EUE 8rd Jt 6.5 L-80 30 Packer, Viking ESP Retr. Dual Vent ~2,000 MD 2-7/8" 30 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" ~1724 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8"8 2-7/8" x 1" GLM, DV installed 6.5 L-80 ~200 MD 2-7/8"10 2-7/8" EUE 8rd Pup Jt 6.5 L-80 2-7/8" 150 2-7/8" EUE 8rd Jt 6.5 L-80 2-7/8" 10 Space out pup 6.5 L-80 2-7/8" 30 Tubing Hanger with full joint 6.5 L-80 33. Terminate the ESP cable and make up the ESP penetrator to the ESP cable. Ensure the 3/8” NPT control line feed thru port is dummied off. 34. Make up the control line to the dual vent valves. Pressure up on the control line to 3,000 psi and hold for 5 minutes checking for leaks (note the opening pressure in the daily report). Bleed the pressure to 500 psi and maintain 500 psi while running in hole. a. Periodically confirm control line is maintaining 500 psi. 35. Continue running ESP completion per plan. Well: MPC-22 PTD: 195-198 API: 50-029-22489-01-00 36. PU and MU the 2-7/8” tubing hanger. Make final splice of the ESP cable to the penetrator. MU the control line to the tubing hanger and dummy off any additional control line ports if present. 37. Land tubing hanger, avoiding any damage to ESP cable or control line. RILDS. Lay down landing joint. Note PU and SO weights on tally and in daily report. 38. Drop ball and rod. 39. Pressure up on tubing to 4,000 psi and hold for 15 minutes to set the ESP packer. 40. Bleed tubing to 0 psi. 41. Pressure up on tubing to 4,000 psi and hold for 5 more minutes and then bleed to 0 psi. 42. Bleed packer control line to 0 psi, closing packer vent valves. 43. Slowly pressure up IA at 50 psi/min to 1,500 psi and hold for 30 minutes. Chart test. 44. Lay down landing joint. 45. Set BPV. 46. RDMO ASR. Post-Rig Procedure: Well Support 1. RD mud boat. RD BOPE house. Move to next well location. 2. RU crane. ND BOPE, set CTS plug, and NU tree. 3. Test tubing hanger void to 500 psi low/5,000 psi high. Pull CTS and BPV. 4. RD crane. Move 500 bbl returns tank and rig mats to next well location. 5. RU well house and flowlines. Slickline: 1. RU slickline, pressure test PCE to 250psi low / 3,500psi high. 2. Pull ball and rod. 3. Pull RHC profile. 4. Pull DGLV and set GLSOV in upper GLM at ~200’ MD. 5. RDMO. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOPE Schematic _____________________________________________________________________________________ Revised By STP 5/15/2019 SCHEMATIC Milne Point Unit Well: MPU C-22A Last Completed: 7/5/2016 PTD: 195-198 TD =9,995 (MD) / TD = 7,254’(TVD) 20” PDS Centralizer Arm lost 6/6/2010 ±9,900’ Orig. KB Elev.: 46/ GL Elev.: 17.4’ (N22E) RT to 7” Hgr = 30.12’ (N 22E) 4-1/2” 2 3 8 & 9 10 9 11 13 & 14 9-5/8” 1 MIN ID= 2.250” @ 7,635’ PBTD =9,905’ (MD) / PBTD = 7,171’(TVD) 5 & 6 4 KUP A2 Sands 7 12 KUP A3 Sands 7” FCO to 9,751’ on 7/03/2016 Window Detail: Top @ 8,435’ Btm @ 8,482’ Mill to 9,900’ 3/14/2011 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / BTC 19.124 Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,715’ 0.0759 7" Production 26 / L-80 / BTC 6.276 Surface 9,253’ 0.0383 4-1/2” Liner 12.6 / L-80 / NSCT 3.958 8,266 9,995’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 7,739’ 0.00579 JEWELRY DETAIL No Depth Item 1 143’ST 2:2-7/8” GLM 2.875” x 1” Patco GLM (BK-2 Orifice Valve Set 7/06/16) 2 7,523’ST 1:2-7/8” GLM 2.875” x 1” Patco GLM (BK-2 Dummy Valve Set 7/06/16) 3 7,635’ 2-7/8” XN-Nipple 2.313 ID packing bore (2.25” No-go ID) 4 7,679’ GPDIS Discharge Head 5&6 7,678’ Pump: 85P37 SXD 7 7,696’ GRSFTX AR H6 Gas Separator 8 7,701’ GSB3DBUT SB/SB PFSA Upper Tandem Seal 9 7,708’ GSB3DBLT SB/SB PFSA CL5 Lower Tandem Seal 10 7,715’ MSP3-250 Motor 11 7,735’ Phoenix XT 150 Sensor 12 7,736’ Centralizer:Bottom @ 7,739’ 13 8,266’ Baker ZXP Liner Top Packer 14 8,281’ Baker 4.5” HMC Liner Hanger: ID=3.958”, Cap= .0152bpf PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status Kup. A3 Sand 9,610’ 9,632’ 6,897’ 6917 22 2-1/2” 12/28/95 Open Kup. A3/A2 Sand 9,636’ 9,666’ 6,921’ 6949 30 2-1/2” 12/28/95 Open 9,666’ 9,692’ 6,949’ 6973 26 3-3/8” 12/26/95 Open Ref Log: 12/23/96 DIL/GR – 2-1/2” 10.5gm. Jumbo Jet Charges @ 90° Phasing – EHD=0.52” / TTP=6.8” // 3-3/8” 22gm. Jumbo Jet Charges @ 60° Phasing – EHD=0.76” / TTP=6.4” OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1300 sx PF ‘E’, 250 sx Class ‘G’’ in a 12-1/4” Hole 7” 150 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 200 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 53° - 55° from 2,650’’ – 7,300’ Hole Angle through perf interval = 23° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 13-5/8” 5M FMC Gen 5, 11” x 2-7/8” FMC Tbg. Hngr., 2.5 “H” BPV profile GENERAL WELL INFO API: 50-029-22489-01-00 Sidetracked, Perfed & Frac’d by Nabors 4ES - 1/1/96 ESP Swap by Nabors 4ES - 8/19/1998 ESP Swap by Nabors 4ES - 10/30/1998 Convert to Gas Lift by Nabors 4ES - 9/23/2002 SLB Frac Job –8/16/2010 Convert to ESP by Doyon 16 –3/17/2011 ESP Swap by Doyon 14 –07/06/2016 STIMULATION SUMMARY 12/28/95 – 91.25M lbs. 20/40 Carbolite behind pipe. 8/16/2010 – Frac with 20/40 & 16/20 ceramic proppant. 98.5M lbs behind pipe. _____________________________________________________________________________________ Revised By TDF 8/21/2025 PROPOSED Milne Point Unit Well: MPU C-22A Last Completed: 7/5/2016 PTD: 195-198 TD =9,995(MD) / TD = 7,254’(TVD) 20” PDS Centralizer Arm lost 6/6/2010 ±9,900’ Orig. KB Elev.: 46/ GL Elev.: 17.4’ (N22E) RT to 7” Hgr = 30.12’ (N 22E) 4-1/2” 6 7 12 &13 14 9 15 17 & 18 9-5/8” 1 MIN ID= 2.250” @ 7,635’ PBTD =9,905’ (MD) / PBTD = 7,171’(TVD) 9 & 10 8 KUP A2 Sands 11 16 KUP A3 Sands 7” FCO to 9,751’ on 7/03/2016 Window Detail: Top @ 8,435’ Btm @ 8,482’ Mill to 9,900’ 3/14/2011 2 3 4 5 KUP B Silt CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 94 / H-40 / BTC 19.124 Surface 112' 0.0355 9-5/8" Surface 40 / L-80 / BTC 8.835 Surface 6,715’ 0.0759 7" Production 26 / L-80 / BTC 6.276 Surface 9,253’ 0.0383 4-1/2” Liner 12.6 / L-80 / NSCT 3.958 8,266 9,995’ 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5 / L-80 / EUE 8rd 2.441 Surface ±X,XXX’ 0.00579 JEWELRY DETAIL No Depth Item 1 ±XXX’ Sta #4:2-7/8” x 1” GLM 2 ±X,XXX’ Sta #3:2-7/8” x 1” GLM 3 ±X,XXX’ Vent packer 4 ±X,XXX’ Sta #2:2-7/8” x 1” GLM 5 ±X,XXX’ 2-7/8” X-Nipple 2.313 ID 6 ±X,XXX’ Sta #1:2-7/8” x 1” GLM 7 ±X,XXX’ 2-7/8” XN-Nipple 2.313 ID packing bore (2.25” No-go ID) 8 ±X,XXX’ Discharge Head: 9 ±X,XXX’ Pump #2: 10 ±X,XXX’ Pump #1: 11 ±X,XXX’ Gas Separator: 12 ±X,XXX’ Upper Tandem Seal: 13 ±X,XXX’ Lower Tandem Seal: 14 ±X,XXX’ Motor: 15 ±X,XXX’ Sensor: 16 ±X,XXX’ Centralizer: Bottom @ ±X,XXX’ 17 8,266’ Baker ZXP Liner Top Packer 18 8,281’ Baker 4.5” HMC Liner Hanger: ID=3.958”, Cap= .0152bpf PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Size Date Status Kup B Silt ±9,424’ ±9,489’ ±6,726’ ±6,786’ ±65 2-1/2” Future Future ±9,510’ ±9,564’ ±6,805’ ±6,855’ ±54 2-1/2” Future Future Kup. A3 Sand 9,610’ 9,632’ 6,897’ 6917 22 2-1/2” 12/28/95 Open Kup. A3/A2 Sand 9,636’ 9,666’ 6,921’ 6949 30 2-1/2” 12/28/95 Open 9,666’ 9,692’ 6,949’ 6973 26 3-3/8” 12/26/95 Open Ref Log: 12/23/96 DIL/GR – 2-1/2” 10.5gm. Jumbo Jet Charges @ 90° Phasing – EHD=0.52” / TTP=6.8” // 3-3/8” 22gm. Jumbo Jet Charges @ 60° Phasing – EHD=0.76” / TTP=6.4” OPEN HOLE / CEMENT DETAIL 20" 250 sx of Arcticset I (Approx) in a 24” Hole 9-5/8" 1300 sx PF ‘E’, 250 sx Class ‘G’’ in a 12-1/4” Hole 7” 150 sx Class ‘G’ in a 8-1/2” Hole 4-1/2” 200 sx Class ‘G’ in a 6” Hole WELL INCLINATION DETAIL KOP @ 500’ Max Hole Angle = 53° - 55° from 2,650’’ – 7,300’ Hole Angle through perf interval = 23° TREE & WELLHEAD Tree Cameron 2-9/16” 5M Wellhead 13-5/8” 5M FMC Gen 5, 11” x 2-7/8” FMC Tbg. Hngr., 2.5 “H” BPV profile GENERAL WELL INFO API: 50-029-22489-01-00 Sidetracked, Perfed & Frac’d by Nabors 4ES - 1/1/96 ESP Swap by Nabors 4ES - 8/19/1998 ESP Swap by Nabors 4ES - 10/30/1998 Convert to Gas Lift by Nabors 4ES - 9/23/2002 SLB Frac Job –8/16/2010 Convert to ESP by Doyon 16 –3/17/2011 ESP Swap by Doyon 14 –07/06/2016 STIMULATION SUMMARY 12/28/95 – 91.25M lbs. 20/40 Carbolite behind pipe. 8/16/2010 – Frac with 20/40 & 16/20 ceramic proppant. 98.5M lbs behind pipe. Milne Point ASR Rig 1 BOPE 2023 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30' Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR STATE OF ALASKA ALGA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations Li Fracture Stimulate Li Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Fill Clean-out 0 Plug for Redrill ❑ 8rforate New Pool ❑ Repair Well 0 Re-enter Susp Well❑ Other: ESP Changeout ❑✓ 2. Name: 4.Well Class Before Work: 5.Permit to Drill Number: Hilcorp Alaska LLC Development 0 Exploratory ❑ 195-198 3.Address: Stratigraphic❑ Service ❑ 6.API Number: 3800 Centerpoint Dr,Suite 1400 Anchorage,AK 99503 50-029-22489-01-00 7.Property Designation(Lease Number): 8.Well Name and LEIVED ADL0047437 MILNE PT UNIT KR C-22A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): L\Li G 16 2016 N/A MILNE POINT/KUPARUK RIVER OIL 11.Present Well Condition Summary: AOGCC Total Depth measured 9,995 feet Plugs measured N/A feet true vertical 7,254 feet Junk measured 9,751(Fill) feet Effective Depth measured 9,751 feet Packer measured 8,266 feet true vertical 7,072 feet true vertical 5,723 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112'......,„.„.._ re 1f53 psi S20psi Surface 6,686' 9-5/8" 6,715' 4,756' 57,580psi 3,090psi Production 8,408' 7" 8,435' 5,847' 7,240psi 5,410psi Liner 1,729' 4-1/2" 9,995' 7,254' 8,430psi 7,500psi Perforation depth Measured depth See Attached Schematic syrr True Vertical depth See Attached Schematic SCANNED JANU1/ Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 7,739' 5,369' Packers and SSSV(type,measured and true vertical depth) ZXP Liner Top N/A See Above N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1,440 0 Subsequent to operation: 98 189 1,682 200 195 14.Attachments(required per 20 AAC 25.070,25.071,&25 283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG LI 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-316 Contact Paul Chan Email pchan(p�hilcorp.com Printed Name Bo York Title Operations Manager Signature ' ��� Phone 777-8345 Date 8/16/2016 cf 'ZL . 4 RBDMS w P:,:_i 1 7 2016 Form 10-404 Revised 5/2015 ,'720 Submit Original Only • . Milne Point Unit SCHEMATIC well: MPU C-22A Last Completed: 7/5/2016 Ilileorp Alaska,W PTD: 195-198 TREE&WELLHEAD Orig.KB Elev.:46/GL Elev.:17.4'(N22E) Tree Cameron 2-9/16"5M RT to 7"yr=30.12' (N 22E) Wellhead 13-5/8"5M FMC Gen 5,11"x 2-7/8" i , 20 FMC Tbg.Hngr.,2.5"H"BPV profile OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I(Approx)in a 24"Hole 11/ 1 9-5/8" 1300 sx PF'E',250 sx Class'G"in a 12-1/4"Hole 7" 150 sx Class'G'in a 8-1/2"Hole 4-1/2" 200 sx Class'G'in a 6"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" _ Conductor 94/H-40/BTC 19.124 Surface 112' 0.0355 9-5/8" Surface 40/L-80/BTC 8.835 Surface 6,715' 0.0759 7" Production 26/L-80/BTC 6.276 Surface 9,253' 0.0383 4-1/2" Liner 12.6/L-80/NSCT 3.958 8,266 1 9,995' 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 7,739' 0.00579 WELL INCLINATION DETAIL STIMULATION SUMMARY KOP @ 500' 12/28/95-91.25M lbs.20/40 Carbolite Max Hole Angle=53°-55°from 2,650"-7,300' behind pipe. Hole Angle through pert interval=23° 8/16/2010-Frac with 20/40&16/20 ceramic proppant.98.5M lbs behind pipe. 9-5/8" 4 O. JEWELRY DETAIL No Depth Item 1 143' ST 2:2-7/8"GLM 2.875"x 1"Patco GLM(BK-2 Orifice Valve Set 7/06/16) 2 7,523' ST 1:2-7/8"GLM 2.875"x 1"Patco GLM(BK-2 Dummy Valve Set 7/06/16) 3 7,635' 2-7/8"XN-Nipple 2.313 ID packing bore(2.25"No-go ID) 4 7,679' GPDIS Discharge Head 5&6 7,678' Pump:85P37 SXD 7 7,696' GRSFTX AR H6 Gas Separator 8 7,701' GSB3DBUT SB/SB PFSA Upper Tandem Seal 2 9 7,708' GSB3DBLT SB/SB PFSA CL5 Lower Tandem Seal MIN ID=2.250"@10 7,715' MSP3-250 Motor 7,635' ------......__, ti 11 7,735' Phoenix XT 150 Sensor 3 12 7,736' Centralizer:Bottom @ 7,739' 13 8,266' Baker ZXP Liner Top Packer 4 14 8,281' Baker 4.5"HMC Liner Hanger:ID=3.958",Cap=.0152bpf 5&6 PERFORATION DETAIL aaail 7 Sands Top(MD) Btm(MD) Top(ND) Btm(ND) FT Size Date Status 1 1 1 8&9 Kup.B Sands 9,610' 9,632' 6,897' 6917 22 2-1/2" 12/28/95 Open p 1 9,636' 9,666' 6,921' 6949 30 2-1/2" 12/28/95 Open Kup.A Sands 9,666' 9,692' 6,949' 6973 26 3-3/8" 12/26/95 Open 10 Ref Log: 12/23/96 DIL/GR-2-1/2"10.5gm.Jumbo Jet Charges @ 90"Phasing-EHD=0.52"/TTP=6.8"//3-3/8" 22gm.Jumbo Jet Charges @ 60"Phasing-EHD=0.76"/TTP=6.4" 11 GENERAL WELL INFO WndowDetail: tinoW Top @ 8 435 12 API:50-029-22489-01-00 Btm@8482' Sidetracked,Perfed&Frac'd by Nabors 4ES -1/1/96 ESP Swap by Nabors 4ES-8/19/1998 7„ .13&14 ESP Swap by Nabors 4ES-10/30/1998 FCOto9,75l'on Convert to Gas Lift by Nabors 4ES-9/23/2002 7/03/2016 =}KUP e Sands SLB Frac Job-8/16/2010 \y _}KUP A Sands PDSCentralizerMn Convert to ESP by Doyon 16-3/17/2011 lost 6/6/2010±9,900 MII to 9,900 ESP Swap by Doyon 16-07/06/2016 4 ~-3/14/2011 1/2"� •,�.. TD=9,995(MD)/TD=7,254'(TVD) PBTD=9,905'(MD)/PBTD=7,171'(TVD) Revised By TDF 8/12/2016 • • Hilcorp Alaska, LLC HileorpAl:u.ka,LL(: Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPC-22A Doyon 14 50-029-22489-01-00 195-198 6/30/2016 7/5/2016 i ` � lilt(ttIR6 � , 1. = 6/29/16-Wednesday 1a }+ No Operations to Report. 6/30/16-ThursdaY t PJSM.Notify DSO.Move off C-15A,position rig mats,line up on C-22A.Secure well,BPV installed,Spot rig over well.Note:0/A=0 psi,I/A=1450 psi.Shim and level rig.Skid rig floor into position.Move rig mats from around C-15A.Rig accepted on C-22A @ 22:00 hrs.R/U rig floor equipment.R/U choke, circulating lines on rig floor and cellar.Spot rock washer and kill tank.Well support R/U hardline.Load 8.5 ppg sea water into pits.Attempt to test lines, leak in unibolt connection on line from Rig choke to kill tank.C/O seal ring. 7/1/16-Friday , R/U circ lines to tree. Test lines to 3000 psi.Good.Pull BPV. Tubing 1200 PSI,Annulus 1400 PSI.Blow down tubing to 0 psi.Blow down Annulus to 20 psi. All gas to Kill tank.Pump down tubing @ 3 bpm.Got fluid back @ 120 bbl away.Crude. Stage up pumps to 5 bpm.Pump total of 580 bbl. Total returned 210 bbl. Got dean seawater back @ 440 bbl away.Shut down&monitor well.Both sides on a vac. Set BPV. N/D tree&verify hanger threads.2 7/8 8rd. Function lock downs.Good.N/U 13 5/8 BOPE dressed with 2 7/8 x 5 VBR in upper and lower BOP,blind ram in middle BOP.PJSM,Pull BPV,Tbg continues on vac,_install_TWC per wellhead rep.R/U Fill line to I/A, fill I/A 10 bph while R/U and testing BOPE.Spot ESP spooling unit.PJSM,R/U test equipme.nt,.perform BOP body test to 3000 psi.eood,AOGCC rep Chuck Scheve waived test witness @ 09:30 am,7/1/16.Test using 2 7/8"and 4"test jts. Test upper and lower 2 7/8 x 5 VBR,blind rams,mud cross valves,choke manifold valves, upper and lower IBOP, 3 FOSVs,2 dart valves to 250 psi low and 3000 psi hi 5 min ea.Test annular w[2 7/8"testjt to 250 low,2500 si hi 5 min ea.Chart record all tests.Perform accumulator drawdown test,N2 bottles 6 @ 1950 psi. Perform hydraulic and manual choke drawdown pressure test.Rig electrician calibrate and test gas alarms.Note:During BOP test fill and monitor I/A @ 10 bph.Attempt to test lower VBR ram w/4"test jt.troubleshoot leak.Continue w/testing,test upper VBR ram. 7/2/16-Saturday #s Finish testing BOPS to 250/3000 psi.Had to repair 4"port in test joint. Had one fail pass on the lower rams&one on the blinds due to improper line up. R/D testing equipment&Blow down all lines.Pull TWC.Well still on a vac.Fill hole.Took 60 bbl.Well loss rate is 60 bbl per hr.Install ESP sheave in the derrick.M/U Landing joint. Install trunk on sheave.B.O.L.D.M/U floor valve._Pull hanger to the floor @ 105K.Terminate ESP cable&hanger.L/D hanger and landing joint. Finish rigging up ESP equipment.R/U Belly Board.PJSM on pulling tubing&standing back in derrick. Inspecting pipe&equipment as we pull.POOH F/8163'T/5572'.Filling the well with double pipe displacement.Continue POH with 2 7/8"ESP completion standing tubing in derrick Inspecting pipe&equipment as we pull F/5572'to pump assy.(L/D 2 GLMs).Recovered 133 Lasalle clamps,6 protectolizers,3 Flat Guard clamps.Filling the well with double pipe displacement.Inspect and L/D Pump assembly per centralift,found small pieces of cmt/fill in upper pump (shaft turns by hand but stiff)Lower pump turns free/intake clear,motor tested good.Last 50'of ESP cable had jacket extruding from armor in several places.L/D trunk, secure and C/O ESP spool,load out pump,load clamps and equipment to rig floor.Continue with hole fill @ 10 bph.RIH with 4 stds 2 7/8"tbg F/derrick, POH L/D 12 excess jts of tbg.4 of the L/D jts crushed from power tongs breaking out.Rig welder prep 2 7/8"mule shoe for cleanout run. Hilcorp Alaska, LLC AilorpAlaska,LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MPC-22A Doyon 14 50-029-22489-01-00 195-198 6/30/2016 7/5/2016 7/3/16-Sunday 1C'77114, d l' Clean&Clear rig floor.M/U Mule shoe&XN nipple with 2.25 no go ID. Inspect threads&pipe while running in the hole. Run in stands of 2 7/8 Dp from the derrick.L/D down 11 joints found with damage from breaking them out. P/U 22 joints of inspected 2 7/8 tubing to get to btm. M/U XO&change handling equipment to 4"dp. P/U 20 jts of 4"dp&stand back in the derrick to use to wash down.Single in the hole w/51 jts 4"DP F/7957'TO 9544',RIH with stds f/derrick tagging @ 9636'@ top of bttm perfs,P/U 117K,S/090K,Bring up pump slowly to 4 bpm,1100 psi,see returns @ 55 bbls pumped. Pump 6 bpm,1920 psi washing down to 9751'with 5k setdown(having to work pipe @ 9705'),R/U headpin,close annular,reverse circulate 2 bpm,300 psi 1.5 volumes,150 bbls.B/U nothing seen @ shaker other than oil mixed returns,shut down pump,open annular.Account for 48 bph loss rate while circulating.Note:235 bbl losses while washing and reverse circ.M/U top drive,attempt to wash past 9751'pumping 5 bpm 1300 psi setting 5k,attempt several times w/no luck seeing 5 to 10k overpull.Rack 1 std back,R/U and POH L/D 4"DP f/9721'to 8053',L/D 3 stds 4"DP in derrick.Filling the well with double pipe displacement.PJSM,Slip and cut 47'drilling line.Reset and test crown saver,service rig.POH L/D last 3 jts 4"DP.Swap to 2 7/8" handling equipment.Drop 2.38"drift on wire. POH racking 2 7/8"tbg in derrick f/7957'to 7682',recover drift on 3rd stand tbg pulled.Drift not heavy enough,fab longer drift.Continue to fill well with double pipe displacement. gi c. Continue POH racking 2 7/8"EUE tbg in derrick f/7682'to 1600'(80 drifted stds of 2 7/8"tbg in derrick)SLM tbg.Filling the well with double pipe displacement.POH L/D remaining 2 7/8"tbg f/1600'to surface,L/D XN nipple.Recover drift.Filling the well with double pipe displacement.PJSM,Run 2 7/8 ESP completion per tally.P/U and M/U mtr/pump asst'as per detail w/centralizer and sensor sub._Fill assy w/oil. torque flanges.M/U Mtr Lead,Meg test same.Filling the well @ 10 bph.M/U 1 jt tbg,XN nipple w/2.25"no go,1 std tbg,2 pup jts w/GLM (dummy valve)2 jts of tbg to 287',RIH w/tbg f/ derrick to 2086'.Install 10 Cannon clamps on 1st 10 jts ran then every other jt.Meg test cable every 2000',Service drawworks,inspect brakes and linkage. Continue RIH w/tbg stds f/2086'to 7100'.Install Cannon clamps on every other jt.Meg test cable every 2000'.Filling the well @ 10 bph. Continue to RIH with 2-7/8 tubing and ESP from 7100'to 7703',installing clamps every other joint.Test cable,M/U tubing hanger/Landing Joint.PUW 102K,SOW 79K.Splice ESP Cable.Lay down and Kick out Misc tools and equipment from rig floor while making final splice.Land Tubing Hanger @ 29.88 RKB,ESP Centralizer @ 7738'. RILDS,Back out and lay down Landing Joint.Install BPV.Clamp count=128 cannon clamps/3 flat guard/5 protectolizers/ 1-1 1/4"SS band,Flush Kill Line/Choke Line/Choke Manifold with FW/Baraklean.Blow down all surface lines.Remove top and bottom rams and blind rams.Continue removing misc equipment from rig floor while pickling the BOP Stack. Continue cleaning Mud Pits and Rock Washer House.Hang Blocks and slip more line on drum.Clean and grease ram cavities.Remove hydraulic lines f/BOPs,clean under drwks and drip pan,Remove shaker screens,clean shaker beds,continue cleaning mud pits.PJSM,N/D BOP and set on pedestal.N/U adaptor flange with 2 9/16" 5M tree.Test tbg hanger void to 500 psi low for 5 min and 5000 psi hi 10 min per wellhead rep,good.Pull BPV.Secure tree.Centralift make final checks.P/U Cellar area,continue to clean Drip pan,inspect gear end chains on mud pumps.disassemble mud cleaner and clean.Clean rock washer and prep for moving,Break out torque tube assembly on top drive,IBOPs,saver sub.Mobilize rig equipment f/rig floor,prep rig floor f/skidding into move position.Skid rig floor into move position.Move rock washer and stage on pad.Inspect rig tires,prep to move rig off well.Rig released from C-22A @ 06:00 hrs. OF Tit THE STATE • • Alaska Oil and Gas om" �M 0A Conservation Commission LAsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p 5 � Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov JAN 0 9 2U17 Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, MPU KR C-22A Permit to Drill Number: 195-198 Sundry Number: 316-316 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED thisay of June, 2016. RBDMS ,VJUN 1 3 2016 r • RECEIVED STATE OF ALASKA JUN 0 6 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION OS Lieti APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑✓ Fill Clean-out Q Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ESP Changeout , Q 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska LLC " Exploratory ❑ Development Q 195-198 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-029-22489-01-00 , 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D • Will planned perforations require a spacing exception? Yes ❑ No 2 / MILNE PT UNIT KR C-22A , 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047437 , MILNE POINT/KUPARUK RIVER OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,995' 7,254' ' 9,905' - 7,171' ' 1,899 None 9,900' Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 112' 112' 1,530psi 520psi Surface 6,686' 9-5/8" 6,715' 4,756' 5,750psi 3,090psi Production 8,408' 7" 8,435' 5,847' 7,240psi 5,410psi Liner 1,729' 4-1/2" 9,995' 7,254' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic I See Attached Schematic 2-7/8" 6.5*/L-80 8,164 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ZXP Liner Top Packer and N/A ,- 8,266'MD t 5,723'ND and N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development❑✓ ` Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/22/2016 Commencing Operations: OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG Cl Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Paul Chan Email pchan@hilcorp.com Printed Name Bo York Title Operations Manager Signature / / Phone 777-8345 Date 6/2/2016 COMMISSION USE ONLY Conditions of appr al: Notify Commission so that a representative may witness Sundry Number. Plug Integrity ❑ BOP Test 1 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3°,0 psi h&P -(-- t zSCx> p5 pv►.,. Y ( s.1--- Post Initial Injection MIT Req'd? Yes ❑ No ❑ I � RBDMS N r 1016 Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: j C7 `- LI Cl�� �� APPROVED BY Approved by: /2 I `� COMMISSIONER THE COMMISSION Date:‘ _ 8_(cs O ` ' Submit Form and Form 10-403 Revised 11/2015 r I cAl'1� d for 12 months from the date of approval. Attachments in Duplicate i i Well Prognosis Well: MPU C-22A kora Alaska,LL' Date:06/02/2015 Well Name: MPU C-22A API Number: 50-029-22489-01 Current Status: Oil Well [Failed ESP] Pad: C-Pad Estimated Start Date: June 22"d, 2016 Rig: Doyon 14 Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 195-198 First Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) Second Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 2,599 psi @ 7,000' TVD (SBHPS 05/30/2016/7.14 ppg EMW) Maximum Expected BHP: 2,599 psi @ 7,000' TVD (No new perfs being added) MPSP: 1899 psi (0.1 psi/ft gas gradient) Brief Well Summary: MPU C-22 was drilled and completed in December 1994 as a Kuparuk River formation producer. The ESP failed in February 1995 and the RWO was unable to retrieve the stuck pump. The well was then sidetracked and fracture stimulated in December 1995. C-22A has had multiple ESPs installed (January 1996 (initial), August 1998 and October 1998) before the well was converted to gas lift in September 2002 due to high GOR and gas slugs. The well was converted back to ESP lift in March 2011. The ESP has failed. Notes Regarding Wellbore Condition • Casing tested to 4,000 psi for 30 minutes down to 8,240' MD on 8/11/2010 • CO 390A: A packer is not required on this ESP completion as the reservoir pressure is less than 8.55 ppg EMW Objective: Pull failed ESP, contingency FCO, and run a new ESP. / Brief RWO Procedure: 1. MIRU Doyon 14 Rig. 2. Pull BPV. Circulate well clean with 8.5 ppg sea water. V 3. Set BPV. ND Tree. NU 13-5/8" BOPE and DSA. Pull BPV and set TWC. 4. Test BOPE to 250 psi low/ psi high, annular to 250 psi low/2,500 psi high (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Doyon 14 BOPE Test Procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Submit completed 10-424 BOPE test results within 5 days of completed test. d. Confirm test pressures per the Sundry Conditions of approval. e. Test VBR rams and annular with 2-7/8" and 4" test joint. f. Test bottom pipe rams and annular with 2-3/8" test joint. 5. Contingency: (If the tubing hanger won't pressure test due to eroded and/or corroded BPV profile and BPV cannot be set with tree on.) . Well Prognosis Well: MPU C-22A Hileorp Alaska,LU Date:06J02/2015 a. Notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 6. Bleed any pressure off tubing and casing to tank. Pull TWC. Kill well w/8.5 ppg seawater as needed. Y 7. MU landing joint or spear and recover the tubing hanger. Contingency(If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. 8. POOH and stand back the 2-7/8"tubing. Tubing will be re-used. Tubing tested good 01/15/2016. Lay down failed ESP. a. Replace bad joints of tubing as necessary. b. Look for over-torqued connections from previous Doyon 16 tubing runs. 9. Inspect the ESP pump section. If the pump section contains carbo-lite frac sand, PU 2-3/8" cleanout assembly and RIH on 4" DP to top of 4-Y2" liner at 8266' MD. Continue RIH and tag fill. (.10. Circulate/reverse circulate wellbore clean to 9904' PBTD. If needed, spot sized salt pill to control losses. POOH and LDDP. C 4J ` a.7 /r?` 11. PU new ESP and RIH on 2-7/8" L-80 tubing '5' a. Upper GLM @ ± 141'w/SO b. Lower GLM @ ±7,506'w/DGLV c. 2-7/8" XN profile @ ±7,628' MD d. Set base of ESP at±7,744' MD 12. Land tubing hanger. RILDS. Lay down landing joint. Note PU (Pick Up) and SO (Slack Off)weights on tally. 13. Set BPV. ND BOPE. NU existing 2-9/16" 5,000#tree/adapter flange. Test tubing hanger void to 500 psi low/5,000 psi high. Pull BPV. 14. RU hot oil and freeze protect well to 2100' MD if needed. 15. RD Doyon 14. 16. Turn well over to production. 17. RU well house and flowlines. • • Well Prognosis Well: MPU C-22A Hileorp Alaska,LLI Date:06/02/2015 Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOPE Schematic 4. Choke Schematic 5. Existing Tree/Wellhead 6. Blank RWO Changes Form Milne Point Unit SCHEMATIC • Well: MPU C-22A • Last Completed: 3/17/2011 !Bleary Alaska.LLC PTD: 195-198 TREE&WELLHEAD Orig.KB Elev.:46/GL Elev.:17.4'(N22E) Tree Cameron 2-9/16"5M RT to 7"Hjgr=30.12' (N 22E) Wellhead 13-5/8"5M FMC Gen 5,11"x 2-7/8" .; L FMC Tbg.Hngr.,2.5"H"BPV profile 2D"A e+ OPEN HOLE/CEMENT DETAIL 20" 250 sx of Arcticset I(Approx)in a 24"Hole 1 9-5/8" 1300 sx PF`E',250 sx Class'G"in a 12-1/4"Hole 7" 150 sx Class'G'in a 8-1/2"Hole 4-1/2" 200 sx Class'G'in a 6"Hole CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40/BTC 19.124 Surface 112' 0.0355 9-5/8" Surface 40/L-80/BTC 8.835 Surface 6,715' 0.0759 7" Production 26/L-80/BTC 6.276 Surface 9,253' 0.0383 , 4-1/2" Liner 12.6/L-80/NSCT 3.958 8,266 9,995' 0.0152 TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf 8,164' 0.00579 WELL INCLINATION DETAIL STIMULATION SUMMARY KOP @ 500' 12/28/95-91.25M lbs.20/40 Carbolite Max Hole Angle=53°-55°from 2,650"-7,300' behind pipe. Hole Angle through perf interval=23° 8/16/2010-Frac with 20/40&16/20 ' ceramic proppant.98.5M lbs behind pipe. 9-5/8" A JEWELRY DETAIL No Depth Item 1 141' GLM STA#2:Camco 2-7/8"x 1"KBMM w/DPSOV 2 7,926' GLM STA#1:Camco 2-7/8"x 1"KBMM w/DGLV 3 8,048' 2-7/8"XN-Nipple(2.25 No-go ID) 4 8,090.6' Discharge Head:GPDIS 5 8,091' Pump:SXD/85-P37 6 8,109' Pump:SXD/18-P75 12 7 8,115' Gas Separator:GRSFTX AR H6 8 8,120' Upper Tandem Seal:GSB3D UT MIN ID=2.250"@ 9 8,127' Upper Tandem Seal:GSB3D LT 8,048' _r 10 8,134' KMH Motor:Rerated 255HP/2,145V/69A '.' , 11 8,160' Pumpmate XTO Sensor (t ' 12 8,162' Centralizer:Bottom @ 8,164' v. r ' I 4 • 13 8,266' Baker ZXP Liner Top Packer 14 8,281' Baker 4.5"HMC Liner Hanger:ID=3.958",Cap=.0152bpf &6 PERFORATION DETAIL 7 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Date Status +8&9 / Kup.BSands 9,610' 9,632' 6,897' 6917 22 2-1/2" 12/28/95 Open R '. 9,636' 9,666' 6,921' 6949 30 2-1/2" 12/28/95 Open Kup.A Sands 9,666' 9,692' 6,949' 6973 26 3-3/8" 12/26/95 Open -'.:10 Ref Log: 12/23/96 DIL/GR-2-1/2"10.5gm.Jumbo Jet Charges @ 90°Phasing-EH D=0.52"/TTP=6.8"//3-3/8" is 22gm.Jumbo Jet Charges @ 60"Phasing-EHD=0.76"/TTP=6.4" z :t ECJ' 11 GENERAL WELL INFO WindowDetail: Top©8,435' 12 API:50-029-22489-01-00 Btm @8,482' y. Sidetracked,Perfed&Frac'd by Nabors 4ES -1/1/96 v, ESP Swap by Nabors 4ES-8/19/1998 7' Ail13&14 ESP Swap byNabors4ES-10/30/1998 _}KUP B Sands Convert to Gas Lift by Nabors 4ES-9/23/2002 WI to 9,9003/14/2011 _ SLB Frac Job-8/16/2010=}KUPASands Convert to ESP by Doyon 16-3/17/2011 PDS Centralizer Ann lost 6/6/2010 4-1/2 ;li TD=9,995(MD)/TD=7,254'(TVD) PBTD=9,905'(MD)/PBTD=7,171'(TVD) Revised By TDF 5/27/2016 • � Milne Point Unit • PROPOSED Well: MPU C-22A Last Completed: 3/17/2011 IIilcorp Alaska,LLC PTD: 195-198 TREE&WELLHEAD Orig.KB Elev.:46/GL Elev.:17.4'(N22E) Tree Cameron 2-9/16"5M RT to 7"Hyr=30.12' (N 22E) Wellhead 13-5/8"5M FMC Gen 5,11"x 2-7/8" w` 44 FMC Tbg.Hngr.,2.5"H"BPV profile 20"4 $* AFF" OPEN HOLE/CEMENT DETAIL ,' " 20" 250 sx of Arcticset I(Approx)in a 24"Hole v 1 r 9-5/8" 1300 sx PF'E',250 sx Class'G"in a 12-1/4"Hole °' 7" 150 sx Class'G'in a 8-1/2"Hole 4-1/2" 200 sx Class`G'in a 6"Hole k', I c Ii CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm BPF 20" Conductor 94/H-40/BTC 19.124 Surface 112' 0.0355 ?"' I r 9-5/8" Surface 40/L-80/BTC 8.835 Surface 6,715' 0.0759 7" Production 26/L-80/BTC 6.276 Surface 9,253' 0.0383 4-1/2" Liner 12.6/L-80/NSCT 3.958 8,266 9,995' 0.0152 ti is. TUBING DETAIL g' 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 Surf ±7,744' 0.00579 WELL INCLINATION DETAIL STIMULATION SUMMARY PKOP @ 500' 12/28/95—91.25M lbs.20/40 Carbolite 44 e: Max Hole Angle=53°-55°from 2,650"—7,300' behind pipe. 1,4 t 1 Hole Angle through perf interval=23° 8/16/2010—Frac with 20/40&16/20 t ceramic proppant.98.5M lbs behind pipe. 9-5/8"«`711 Mi' JEWELRY DETAIL No Depth Item 1 ±141' GLM STA#2: 2 ±7,506' GLM STA#1: 3 ±7,628' 2-7/8"XN-Nipple(2.25 No-go ID) 4 Discharge Head 5 Pump:SXD/85-P37 6 Pump 7 Gas Separator 2 8 Upper Tandem Seal MINID=2.250"@ 9 Upper Tandem Seal +7,628' >i r 10 KMH Motor 3 11 Pumpmate XTO Sensor 9 12 ±7,744' Centralizer:Bottom @±8,164' 4 13 8,266' Baker ZXP Liner Top Packer 14 8,281' Baker 4.5"HMC Liner Hanger:ID=3.958",Cap=.0152bpf i tt 5&6 PERFORATION DETAIL Il 7 Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Size Date Status 8&9 Kup.BSands 9,610' 9,632' 6,897' 6917 22 2-1/2" 12/28/95 Open 9,636' 9,666' 6,921' 6949 30 2-1/2" 12/28/95 Open t p Ku .A Sands Il kz" 9,666' 9,692' 6,949' 6973 ° 26 3-3/8" 12/26/95 Open K10 12/23/96DIL R-2-1 2 1 m.JumboCharges 90 Phasing—EHD=0.52' TTP=6.8"113-3/8" Ref Log: G 0 5 Jet + gg : 22gm.Jumbo Jet Charges @ 60°Phasing—EHD=0.76"/TTP=6.4" '' Mnrx t1 r11 GENERAL WELL INFO Vbindw✓Detail ; 12 �, API:50-029-22489-01-00 Top @8,435' Sidetracked,Perfed&Frac'd byNabors 4ES -1/1/96 Btm @ 8,482 '3 * ESP Swap by Nabors 4ES-8/19/1998 7 X141 5t413&14 ESP Swap by Nabors 4ES-10/30/1998 _}KUP B Sands Convert to Gas Lift by Nabors 4ES-9/23/2002 MII to 9,900 3/14/2011 SLB Frac Job—8/16/2010 _}KUP ASands Convert to ESP by Doyon 16—3/17/2011 PDS Centralizer Mn lost 6/6/2010 4-1/2"/ : , TD=9,995(MD)/TD=7,254'(TVD) PBTD=9,905'(MD)/PBTD=7,171'(TVD) Revised By PC 06/02/2016 1/04/18• • DOYON 14 BOP'S DRILLING 19-5/8 5000 PSI RIG FLOOR -_ n n n n n HYDRIC 13-5/8" ANNULAR \ fif / Sz .0 "GE" 5000 00FLANGE v .HYDRIC. V • / 0 • / I I:I:II:I1:1 I:I I:II:I:IiI HYDRH. MPL DOUBLE GATE I _ o I O 19-5/8" 5000 PSI °' �*� :� o ��'O' STUD z STUD BX-180 IZ� „�•.y� � O ri M 10" OPERATORS -- —r--rres PIPE RAMS � G ~ O sum: ---:ter- 1 in in 10" OPERATORS G, ra':� 1 1. IINI BLIND RAMS \ 3-1/8" 5000 PSI MANUAL VALVE 3-1/8" 5000 PSI HCR VALVE JII1 -- 1)-- - 17 -- __ _ Cr MI MUD CROSS / 13-5/8" 5000 PSI FLANGE x FLANGE BX-180 nn.u.Civ iv l.n.i.r.l WITH lEA. 3-1/8" & 4-1/16"OUTLETS •-- - - - --- HYDRIL MPL SINGLE GATE JEW — NM - \ O 13-5/8" 5000 PSI °��1„ t� ° FLANGE x FLANGE BX-180 CK ! - �RE 10" OPERATORS I ' '' .l —� i1 M PIPE RAMS ' i lin ■� j1 _ IIUIUIIUI.IUI IUIIUIIUIUIU TUBING SPOOL -1 1- I -(411$1 - INI ' GROUND LEVEL i I II • 0 cn ct T-•• ----• 0 elitk ;...ict , i fa, 0 w ,1„,:t . HI CID AIN :01.11 1111 . kr' t 41k 0 IP a) .\,,. 4-, E p.., f. 4 / „ V. _. _ -_ • AU ' 4U p cl.) •- .4-) ;--1 • Cll =I o 0 „_ , am.-....... III. ... ek - Z 1. .... ti cpp) „_..., ci vi cs -0 ( > > a; -a a) a) > > .. a)Lt _c-6 > 0 a. u 4' W (7 7, 1 LUI Ce Er) a) a) 7E) 0 > Ta > v) a) > a) •— cc) ce -0 Z E < i-r) E E - -0 c ......71 11 ID a) a) ..-- v) rn =0- eL -0 0 • c 0 0 0 i:-.) L.() Z Ln Oo ":0 - — cdZo _ rn V I W I ca >. -15 >, ee 2 — c — a a) T's cd Td 1- , > --.. , . c.,s . , s_ co v rn rsi aS (II) co • •• -v) U •Ln •in- . 0 411\ tit a; n 7, WI • • 4--) ‘../ > -0 > > ....j Z II r mfr. 3 >. _-_-_-• 1 RI i:-.7i Cr.' F4 0 • w S� \2 oF Willi Date: 3/17/2011 Rig: Doyon 16 —h0='s• Well Number: MPC-22 1[..p*Ill MIMI 0I 1111 lTNOH.r°0 t. 1 MIM. — NMI.1111•.111111_ SII 11" 5000 FIG. r' 471 / / UJLLIILL.11►-21LII .0 " 28.50" FMC ,k . �3 O . / 13 5/8" 5000 FLG. 0' fa:4 4LUJ LL.11 LI-LI 11.11 .) FMC ''4.O ` 22.50" \ I M 13 3/8" SOW �� O 1 / 8.50" 1 r` I X 13.0" fj pII • S ,:, ....... = a) r' m .>_ (a a) = V 0 IX05 ai UT = U � UQa °' E a) Q E• rn o n w U El a) 03 a) O Y O> Ew — a) lav L.E Q m • 0 a) -o \/ o 92 a ' 2 mQ a L aa a >, IL) m ns as o 0 0 (n C a) (a Cr)-CCo (a a) O U "5 o w a) o a � Q V N '0Q O N a)• (a a) a C) U o = _ a) o_'' (a a 2 QL 0 U E m CO a ami0 a) y O L. ,o a Q O -0 a) m sp O a. 3 TSS v L Ch a \J V U) L L ll > > C) Fes"( O O `. R) _ O 0. Q a) d as C CKF Q Q RS 0 co 22 W O C - a N N .� C/) Q. N N O O O v) Q a) a N C) rn . i i C CO O a) a) a) a) oV) a v o a 0 a.0 v 0 = '_, Ri .. a) .0 E CO a o co V o v) U) CO Q a`. STATE OF ALASKA • ALASKf. AND GAS CONSERVATION COMMIS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon r2 Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ∎ 4 Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Run ESP Completion 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory r 195 - 198 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 a 50 - 029 - 22489 - 01 4 Q 0 7. Property Designation: 8. Well Name and Number: ADL 047434 & 047437 + MPC - 22A 9. Field / Pool(s): o Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 9995 feet Plugs (measured) None feet true vertical 7254 feet Junk (measured) Yes, unknown Effective depth: measured 9905 feet Packer: (measured) None feet true vertical 7171 feet Packer: (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1530 520 Surface 6885' 9-5/8" 6715' 4756' 6870 4760 Intermediate Production 8408' 7" 8435' 5847' 7240 5410 Liner 1729' 4-1/2" 8266' - 9995' 5722' - 7254' 8430 7500 ti. , 'z- APP 07 `•011 Perforation Depth: Measured Depth: 9610' - 9692' True Vertical Depth: 6897' - 6973' Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L - 8164' MD 5651' TVD Packers and SSSV (type, measured and true vertical depth): None 11. Stimulation or cement squeeze summary: RECEIVE; Intervals treated (measured): MAR Treatment description including volumes used and final pressure: mas gii 111 & gas C lw 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 40 0 Subsequent to operation: 156 417 809 780 808 13. Attachments: ❑Copies of Logs and Surveys run 14. Well Class after work: y ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations ■:+ Well Schematic Diagram 15. Well Status after work: ❑ GINJ wig Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Elizabeth Barker, 564 -5674 N/A Printed Name '// 2,2 {{ � e f- � �/1 u h 4 � ke ^ Title Drilling Technologist Signature 7j �% i . � Prepared By Nene5: Phone 564 -5674 Date 3 30 ',20/ /, Eliz abeth Barker, 564-5674 Form 10-404 Revised 10/2= A-1.4.11 Submit Original Only RBDAAS APR 01.20 P ,Sl tr(/i Tree: 2 9/16 " - 5M Cameron • MPC-22A Orig. RT Elev. - (N 22E) Wellhead: 13 5/8" 5M FMC Orig. GL Elev. .4' 11" X 2.7/8" FMC tubing hanger RT to 7' Hgr = 30.12 (N 22E) CIW 2.5" H BPV profile. IL 20" 94 ppf, H -40 BTC 112' Camco 2 -7/8" x 1" 141' KOP @ 500' sidepocket KBMM GLM Max. hole angle = 53 - 550 deg @ 2650 - 7300' Hole angle thru perfs = 230 deg 9 5/8 ", 40 ppf, L -80 BTC 6715' 2 7/8", 6.5#, L-80 8rd EUE (drift ID = 2.347 ", cap. = 0.0058 bpf) 7" 26 ppf, L -80, Btrc. prod. casing,_ ( drift ID = 6.151 ", cap. = 0.0383 bpf ) (Cap w/ 2 7/8" tbg inside = 0.02758 bpf) Camco 2 -7/8" x 1" I 7926' sidepocket KBMM GLM 2 -7/8" XN nipple 1 8048` • (ID 2.250 ") KIT Stimulation Summary 4 Tandem Pump. 12/28/95 91.25M Ibs of 20 -40 carbolite behind 85 - P37 SXD & 18 - P75 SXD 1 8090` pipe. Kup 'A' sand job went to flush. EA Tandem Gas Separator 8115' GRSFTX AR H6 7, Intake= 5618' TVD Perforation Summary Ref log: 12/23/96 DIL / GR Tandem Seal Section 1 8120` Model GSB3BD UT /LT derisi Si7P SPF Interval (TVD) Motor, Rerated 225 HP, 8134' KUP 'B' Sand a. 2145 volt, 69 amp, Model KMH 2 1/2 4 9610' - 9632' (6897'- 6918') NM A KUP 'A' Sand 2 1/2 4 9636' - 9666' (6921'- 6949') PumpMate w/6 fin Centralizer 8159' 3 3/8 6 9666' - 9692 (6949'- 6973') ( PumpMate = 5647' TVD 2 1/2 guns loaded w/ 10.5 gm jumbo jet charges (EHD = 0.52 ", TTP = 6.8 ") w/ 90 deg phasing ( 8266' 3 3/8" gun loaded w/ 22 gm jumbo jet charges Baker ZXP liner top packer (EHD = 0.76 ", TTP = 6.4 ") w/ 60 deg phasing Baker 4.5" HMC liner hanger 1 8281' I NI Liner 4.5" 12.6 ppf, L -80, NSCT (ID = 3.958 ", Cap. = .0152 bpf) Top of window 8435' and o . Note; PDS centralizer arm was lost during the ■ caliper survey on 6/6/10. / y Original Hole / / ` 4 1/2" float collar (PBTD) I 9904' I Fit tagged at 9885' wlm on 12/26/09 , , 41/2" float shoe 1 9995' DATE REV. BY COMMENTS MILNE POINT UNIT 12/31/95 JBF Well bore sidetracked by Nabors 4ES 8/22/98 MDO ESP RWO by Nabors 4ES WELL C -22A 10/31/98 M. Linder RWO by Nabors 4ES API NO: 50 - 029 - 22489 - 9/23/02 L. Hulme Convert to Gas Lift Well (Nabors 4ES) 3/15/11 L. Hulme Convert to ESP (Doyon 16) BP EXPLORATION (AK) • • MPC -22A Well History (Pre -Rig Workover) Date Summary 2/18/2011 RAN 1.80" CENT,S.S & DUAL SPARTEK GAUGES.MADE 15 MINUTE STOP @ 9000' MD & 3 HOUR STOP @ 9550' MD. 2/19/2011 Pumped 50bbls crude and diesel down tubing while SL set plug. MIT -T to 1600psi PASSED. Pumped 0.7bbls crude to pressure up. Tubing lost 80psi 1st 15min, 30psi 2nd 15min, for a total of 110psi in 30min.. Bled to 280psi. MITIA to 1000psi PASSED. Pressured up w/ 105.7bbls. IA lost 60psi 1st 15min, 20psi 2nd 15min, for a total of 80psi in 30min. MITOA to 2000psi FAILED. Pressured up OA to 1940 w/ 4bbls. OA broke free. LLR = 1.5bpm @ 1350psi, and steadily getting worse. 2/19/2011 SET 2.313" XXN PLUG W/ 12" FILL EXTENSION (eqz sub has 8- 3/32" ports /oal -36 ") @ 8266' MD. LRS MIT- T /IA/OA. PASSED. PULLED 1" DUMMY FROM 8180' MD. 2/20/2011 CUT 2 -7/8" TUBING WITH 2.125" POWER CUTTER. CUT DEPTH: 8232'. QCL TO CUTTER: 6.3'. CCL STOP DEPTH: 8225.7' 2/21/2011 CMIT TxIA PASSED at 500psi and 1000psi. (Post TBG Jet Cut) Pumped 17.5bbls to pressure up to 500psi. IA and Tubing lost Opsi in 30min. Pumped additional 0.8bbls to pressure up to 1000psi. IA and Tubing lost Opsi in 30min. Bled all pressures to zero. 2/22/2011 The Well Support Techs rigged up and installed a BPV . Page 1 of 1 • • • 't a r— =."�'�` Sa ,_..m >— L I e . l l 1 r Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4 -00T4Q E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 ©39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 3/6/2011 00:00 - 01:00 1.00 MOB P PRE PJSM. MOVE OFF WELL. -RAISE CELLAR DOORS. CALL PAD OP. -PAD OP WATCHED RIG MOVE OFF WELL. 01:00 - 02:00 1.00 MOB P PRE REMOVE STACK & PLACE ON TRAVEL STAND. - C /O SPACER SPOOL TO 13 -5/8" X 13 -5/8 ". 02:00 - 04:00 2.00 MOB P PRE T ROV T O STAGE URN R IG. M &INSTALL E OA END REAR F BOO STERS. 04:00 - 06:00 2.00 MOB P PRE REPAIR COUPLER ON HYDRAULIC DRIVE FOR MOVING SYSTEM. 06:00 - 10:30 4.50 MOB P PRE MOVE RICA -TO C -PAD. 10:30 - 18:00 7.50 MOB P PRE PULL ONTO MPU C PAD AND PREP LOCATION. - RAISE DERRICK. -SPOT RIG OVER MPC -22 AND SET DOWN . 18:00 - 21:00 3.00 RIGU P DECOMP SECURE DERRICK: RI SQUEEZE M ANIFOLD IN CELLAR. -IA= 40 PSI. OA= 180 PSI. -SPOT FUEL TRAILER & SLOP TANK. -TAKE ON 9.7 PPG NACL BRINE. -ACCEPT RIG @ 18:30 HRS. 21:00 - 23:00 2.00 RIGU P DECOMP R /U BACK TANK & HARDLINE. -TEST HARDLINE. 23:00 - 00:00 1.00 RIGU P DECOMP RIG EVACUATION DRILL WITH ALL PERSONNEL ON LOCATION. - AAR FOR DRILL. 3/7/2011 00:00 01:00 1.00 RIGU P DECOMP RIG EVACUATION DRILL WITH ALL PERSONNEL ON LOCATION. -AAR FOR DRILL. 01:00 - 02:30 1.50 PULL P DECOMP PJSM. TEST CIRC LINES TO 3000 PSI. - BULLHEAD 189 BBLS OF 9.7 PPG NACL. -ICP= 1420 PSI @ 2 BPM. - FCP= 940 PSI @ 5 BPM. 02:30 - 04:30 2.00 PULL P DECOMP M BUILD UP. B BBLS EVERY ONITOR 5 MIN & TREND BLEED / TRACK. ACK 5 04:30 - 06:30 2.00 PULL P DECOMP P/U DSM LUBRICATOR. -TEST LUBRICATOR 250 LOW PSI 3500 HIGH PSI. -PULL BPV HAD 300 PSI ON TBG 0 PSI ON IA. -R/D LUBRICATOR. 06:30 - 10:30 4.00 KILLW P DECOMP TERFA T - CIRCPJSM. ULATE ST OUT FREEZE CE PROTECT LINES O 3000 AND PSI. 10.7 PPG BRINE. RESE R BBLS T - CIRCU CI LONG C 52 WAY 635 OUT TB TO GET UBING. CLEAN 9.7 BRINE BACK. - 4 BPM AT 600 TO 800 PSI. 10:30 - 11:00 0.50 WHSUR P DECOMP MONITOR WELL AND B/D SURFACE LINES FROM CIRCULATING. 11:00 - 12:00 1.00 WHSUR P DECOMP SET TWC AND TEST 250 LOW AND 1000 PSI HIGH FROM BELOW. -TEST 250 LOW AND 3500 HIGH FROM ABOVE. 12:00 - 13:30 1.50 WHSUR P DECOMP R/D SQUEEZE MANIFOLD & CIRC LINES IN CELLAR. -BLEED OA 1 -GAL. FMC BLEED TBG VOID. Printed 3/30/2011 2:31:39PM ) 'America. - ALASKA B? . rya E t p ti ©n Summary R E` €: Akik: Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 16:30 3.00 WHSUR P DECOMP R/U BLEED HOSE TO FLOW BACK TANK & BLEED OA. -N /D TRFF & ADAPTOR FLAN(IF _ - -- 8.5 TURNS ON XO TO PULL TBG HANGER- - 16:30 - 20:30 4.00 WHSUR P DECOMP N/U BOPE. TORQUE SPACER SPOOL ADAPTOR. 20:30 - 00:00 3.50 WHSUR P DECOMP TEST ROPF• D -TEST 2 -7/8" AND 4" TIW VALVES, DART bo VALVES. / y. -TEST RAMS W/ 2 -7/8" & 4" TEST JTS. -TEST ANNULAR W/ 2 -7/8" TEST JT. -TEST TO: 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES. - AOGCC, BOB NOBLE, WAIVED WITNESS. -ALL TESTS WITNESSED BY BP WSL & DDI TP. 3/8/2011 00:00 - 01:30 1.50 WHSUR P DECOMP CONTINUE TO TEST BOPE: -TEST 2 -7/8" AND 4" TIW VALVES, DART VALVES. -TEST RAMS W/ 2 -7/8" & 4" TEST JTS. - TEST ANNULAR W/ 2 -7/8" TEST JT. -TEST TO: 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES. -AOGCC, BOB NOBLE, WAIVED WITNESS. -ALL TESTS WITNESSED BY BP WSL & DDI TP. - COMPLETE DERRICK INSPECTION. 01:30 - 03:00 1.50 WHSUR P DECOMP INSTALL DUTCH RISER SYSTEM. -P /U 2 -7/8" HANDLING EQUIPMENT. -M /U JT OF DP TO XO TO HANGER. 03:00 - 04:30 1.50 WHSUR P DECOMP RIG SERVICE. INSPECT DERRICK & TOP DRIVE. 04:30 - 05:00 0.50 WHSUR N ` DECOMP WAIT ON VALVE SHOP. 05:00 - 07:00 2.00 WHSUR P DECOMP P/U 150" LUBRICATOR. -TEST TO 250 PSI LOW AND 3500 PSI HIGH PRESSURE. -PULL TWC. 07:00 - 07:30 0.50 PULL P DECOMP M/U LANDING JOINT TO HANGER. - BOLDS. -PULL BANGER TO Rin Fl (1fR HAN(;FR CAME FREE AT 75K. . 07:30 - 08:00 0.50 PULL P DECOMP B/O AND UD HANGER. -M /U 2 -7/8" XO. -RIH 15' AND CLOSE ANNULAR. 08:00 - 11:00 3.00 PULL P DECOMP CIRCULATE THROUGH CHOKE. -PUMP AT 5 BPM WITH 835 PSI. - MONITOR WELL SHOWING SLIGHT FLOW. - CIRCULATE AGAIN AT 5 BPM AND 1061 PSI. - MONITOR WELL. STATIC. -KWF 9.7 PPG BRINE. 11:00 - 12:00 1.00 PULL P DECOMP L/D 4 JOINTS OF 2 -7/8" TUBING. -UD 1 TEN FOOT PUP JOINT. -UP WEIGHT 75K, DOWN WT 70K. 12:00 - 16:00 4.00 PULL P DECOMP P/U 4" DP OUT OF PIPE SHED. -MAKE L- SHAPE CRADLE FOR RACKING BACK 2 -7/8" TUBING IN DERRICK. 16:00 - 16:30 0.50 PULL P DECOMP R/D DP EQUIPMENT. -M /U FLOOR VALVE AND XO FOR 2 -7/8" TUBING. Printed 3/30/2011 2:31:39PM `�- I i Rte .prai�t` � tt a " e Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 00:00 7.50 PULL P DECOMP POOH RACKING BACK 79 STANDS OF 2 -7/8" TUBING. -4 -GLMS. - CHANGE OUT BAD JOINTS #189, 209, 227, AS REQUESTED. 3/9/2011 00:00 - 01:30 1.50 PULL P DECOMP CONTINUE TO POH AND STAND 2 -7/8" TBG IN DERRICK. -TOTAL GLM POH IS 5 EA. -TOTAL TBG JOINTS OF 255 EA. -84 STANDS OF TUBING RACKED BACK IN DERRICK. -TOTAL OF 6 JOINTS OF TUBING IN PIPE SHED FROM WELL. -1 X-NIPPLE. -CUT JOINT OF 2.85' IN LENGTH AND GOOD FLARE TO 3-5/16". 01:30 - 02:30 1.00 PULL P DECOMP CLEAN RIG FLOOR. 02:30 - 04:30 2.00 PULL P DECOMP P ,/U 6-1/8" DRESS OFF BHA 04:30 - 14:00 9.50 PULL P DECOMP P/U 234 JTS 4" DP FROM PIPE SHED 1X1. AND'RIH WITH BHA #1 TO 8014' MD. 148K UP WEIGHT, 108K DOWN WEIGHT. 14:00 - 15:30 1.50 PULL P DECOMP P/U STORM PACKER AS PER HALIBURTON HAND. -P /U 3 JOINTS DP AND SET STORM PACKER 1 STAND BELOW WELL HEAD (98'). -TEST STORM PACKER TO 250 PSI LOW AND _ 1000 PSI HIGH FOR 10 MIN. GOOD TEST. 15:30 - 16:30 1.00 PULL P DECOMP RD SETTING TOOL. -BLOW DOWN HOLE FILL AND KILL LINE. -DRAIN STACK. 16:30 - 17:30 1.00 WHSUB P DECOMP PJSM FOR WD BOPE. -N /D BOPE. -TWO BARRIERS ARE STORM PACKER AND TTP IN XN. 17:30 - 00:00 6.50 WHSUB P DECOMP PULL TUBING SPOOL AND PACK OFF. - REMOVE PACK OFF WITH 20K OVER. - ATTEMPT TO PULL TUBING SPOOL HAVING _ DIFFICULTIES. PULLING 10 -20K OVER 3/10/2011 00:00 - 02:00 2.00 WHSUB P DECOMP CONTINUE TO WORK ON FREEING TUBING SPOOL. -SPOOL BOLTS RUSTED AND HOLDING SPOOL IN PLACE. 02:00 - 03:00 1.00 WHSUB P DECOMP INSTALL NEW TUBING SPOOL AND PACK OFF. 03:00 - 06:00 3.00 WHSUB P DECOMP TEST PACK OFF TO 250 PSI LOW AND 5000 _ PSI HIGH. CHART FOR 30 MIN. 06:00 - 08:00 2.00 BOPSUR P DECOMP PJSM - CHANGE OUT BOP ADAPTOR FLANGE TO 13 5/8 "X 11" -MU DOUBLE ANNULUS VALVES - NU BOP 08:00 - 08:30 0.50 BOPSUR P DECOMP SET TEST PLUG -TEST BOP BREAKS TO 250 LOW, 3500 PSI HIGH CHARTED FOR 5 MIN. 08:30 - 09:00 0.50 I WHSUR P DECOMP SET WEAR RING -BREAK DOWN RUNNING TOOL Printed 3/30/2011 2:31:39PM America ALAS A BP Pad (tea Operation Summery, Report Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 10:30 1.50 BOPSUR P DECOMP TEST 2 -7/8" TIW VALVE AND 2 -7/8" DART VALVE -LOW 250 PSI, HIGH 3500 PSI -5 CHARTED MINUTES 10:30 - 12:00 1.50 DHB P DECOMP PJSM - RELEASE 7" STORM PACKER -MONITOR WELL - CIRCULATE BOTTOMS UP FROM STORM PACKER DEPTH AT 2 BPM AT 1600 PSI -LAY DOWN STORM PACKER -CIRCULATE BOTTOMS 5 BPM AT 650 PSI 12:00 - 14:00 2.00 FISH P DECOMP PICK UP 1 STAND OF 4" DP -TAG TUBING STUB AT 8215' -DRESS OFF STUB -7.5' OF SWALLOW TO 8222' - MONITOR WELL 14:00 - 17:30 3.50 FISH P DECOMP POOH, STAND BACK 4" DP - CONTINUOUS HOLE FILL -9.7 PPG BRINE. - MONITOR WELL. STATIC. 17:30 - 18:30 1.00 FISH P DECOMP POOH WITH THE DRILL COLLARS. -STAND BACK DC IN DERRICK. 18:30 - 19:30 1.00 FISH P DECOMP POOH WITH THE DRESS OFF BHA. 19:30 - 00:00 4.50 FISH P DECOMP MAKE UP NEW PACKER MILL BHA. -RIH WITH DP OUT OF DERRICK. - RIH TO 8173'. - OBTAIN SPRS OF 20 SPM AND 120 PSI, 30 SPM AND 230 PSI. -UP WT OF 168K, DOWN WT OF 11 OK, ROT WT OF 125K, 40 RPM AND 5K OF TQ. 3/11/2011 00:00 - 02:30 2.50 FISH P DECOMP RIH AND TAG TOP OF PACKER AT 8223' - OBTAIN PARAMETERS OF 168K UP, 110K DOWN, 130K ROTATING. -BEGIN MILLING OPERATIONS AT 7 -10K WT ON BIT, 60 -80 RPM, 4 BPM AT 490 PSI AND 7 -11 K TORQUE. - MILLED 1' INTO PACKER AND OBSERVED FLOW INCREASE BY 10 %. -SHUT DOWN PUMPS AND MONITOR WELL. WELL FLOWING SLIGHTLY. -SHUT IN ANNULAR, NO PRESSURES SEEN ON DP OR IA. 02:30 - 04:30 2.00 FISH P DECOMP WITH ANNULAR SHUT IN. - ATTEMPT TO BULL HEAD 9.7 PPG BRINE. PRESSURE INCREASED TO 3100 PSI IN 12 BBLS. -SHUT DOWN PUMPS AND SEEN REAL SLOW DROP IN PRESSURE. -BLED DOWN TO 0 PSI. - NOTIFY DAY WSL AND RWO SUPERINTENDANT. - CIRCULATE BOTTOMS UP THROUGH CHOKE AT 6 BPM AND 664 PSI. - MONITOR WELL FOR 15 MIN. WELL STATIC. 04:30 - 06:00 1.50 FISH P DECOMP OPEN ANNULAR. -BEGIN MILLING OPERATIONS AT 7 -1 OK WT ON BIT, 60 -80 RPM, 4 BPM AT 490 PSI AND 7-11K TORQUE. Printed 3/30/2011 2:31:39PM art rth America to‘ B 13 Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) • Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 09:30 3.50 FISH P DECOMP CLOSE ANNULAR DUE TO BUBBLES IN FLOW, WITH PUMP ON - CIRCULATE BOTTOMS UP OF 237 BBLS AT 4 BPM & 360 PSI THROUGH GAS BUSTER - RETURNS MIXED WITH OIL THROUGH OUT COMPLETE CIRCULATION. ATTEMPT TO BULLHEAD -12 BBLS PUMPED TO 3100 PSI AT 4 BPM -100 PSI BLEED OFF IN 1 MIN -DISCUSSED PLAN FORWARD WITH RWO SUPT CIRCULATE BOTTOMS UP 256 BBLS AT 5 BPM THROUGH GASBUSTER - RETURNS MIXED WITH OIL THROUGH OUT CIRCULATION. -SHUT DOWN PUMP AND MONITOR WELL FOR 30 MIN -WELL STATIC WITH BUBBLES -O PSI ON DRILLPIPE AND ANNULUS -OPEN ANNULAR COORDINATED WITH RWO SUPT AND RWO ENGINEER MULTIPLE TIMES DURING CIRCULATING OPERATIONS TO DETERMINE PLAN FORWARD 09:30 - 10:30 1.00 FISH P DECOMP CONTINUE MILLING @ 0930 WHILE PUMPING 3 BPM AT 420 PSI - MILLING PARAMETERS: 80 RPM, 9 -11.5K TORQUE, 10 -13K WOB -PUMP 20 BBL HI-VIS SWEEP -WHEN BOTTOMS UP CAME FROM THE 30 MIN SHUT -IN, RETURNS HAD INCREASED AMOUNT OF OIL Printed 3/30/2011 2:31:39PM n €� _ e. O, € 1 [t[" € Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/19 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 15:00 4.50 FISH P DECOMP FLOW INCREASE BY 10 %, PUMP PRESSURE DECREASE - OBSERVED WELL PERCOLATING, NO FLOW. -SI ANNULAR AND CIRCULATE BOTTOMS UP WITH 240 BBLS AT 4 BPM THROUGH GAS BUSTER -NO PIT LOSS OR GAIN. RETURNS MIXED WITH OIL THROUGH OUT CIRCULATION. ATTEMPT TO BULLHEAD -4.7 BBLS TO REACH 3100 PSI AT 4 BPM -AFTER 1 MIN WITH PUMP DOWN 2200 PSI -AFTER 2 MIN 1700,. PSI CIRCULATE BOTTOMS UP AT 4 BPM THROUGH GAS BUSTER -FLOW CHECK, NO FLOW -OPEN ANNULAR RETURNS MIXED WITH OIL THROUGH OUT CIRCULATION. RECOVERED 12 BBLS OF OIL FROM RETURN PIT CONTINUE MILLING @ 1230 -80 RPM, 3 BPM, 200 PSI -DRY MILL, 9 -11 K TORQUE, 10 WOB -NO FOOTAGE MADE - BOTTOMS UP PUMPED WHILE MILLING, OIL STILL VISIBLE BUT NO CHANGE IN AMOUNT SHUTDOWN PUMP AND PICK UP OFF BOTTOM -STRAP PITS AND SKIM OIL OFF THE TOP -RE STRAP TO DETERMINE 21 BBLS OF OIL OUT TO SLOP TANK (DAILY TOTAL OF 33 BBLS AERATED OIL) COORDINATED WITH RWO SUPT AND RWO ENGINEER MULTIPLE TIMES DURING MILLING AND CIRCULATING OPERATIONS TO DETERMINE PLAN FORWARD. CONCLUSION: KWF SWAPPING WITH WELL BORE FLUIDS (-20 - 25 BBLS CALCULATED PACKER FLUID VOLUME COMPARED TO 33 BBLS OF EMULSIFIED WELL BORE FLUIDS RECOVERED AT SURFACE). 15:00 - 16:00 1.00 FISH P DECOMP MONITOR WELL FOR 1 HOUR - STATIC WITH BUBBLES BREAKING OUT, NO GAINS OR LOSSES -PJSM, WEEKLY CREW CHANGE FROM TOWN Printed 3/30/2011 2:31:39PM � � I L�SKA� � a t 4 �' t l � TAt € R ? H Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:30 1.50 FISH P DECOMP CONTINUE MILLING -SLOW PUMP RATES 1 BPM @ 20 PSI 2 BPM @ 70 PSI 3 BPM @ 120 PSI - CIRCULATE BOTTOMS UP AT 3 BPM WHILE MILLING -MILLING PARAMETERS: 5 -15k WOB, VERY PUMP RATES AND STILL NO PROGRESS. 17:30 - 19:00 1.50 FISH P DECOMP CIRCULATED BOTTOMS UP. - PUMP AT 4 BPM AND 360 PSI. - NO WELL BORE FLUIDS OBSERVED DURING CIRCULATION. -IN ALL ABOVE THERE WAS NO GAIN IN FLUID LEVELS DUE TO CRUDE SWAPPING OUT WITH 9.7 PPG BRINE FROM UNDER THE PACKER AND THE FACT THAT WE COULD NEVER BULLHEAD. -MONITOR WELL FOR 30 MIN. - STATIC. 19:00 - 00:00 5.00 FISH P DECOMP POOH FOR MILL CHANGE. -POOH TO DC AND MONITOR WELL. STATIC. -POOH AND L/D BHA, CLEAN OUT BOOT BASKETS. 3/12/2011 00:00 - 01:00 1.00 FISH P DECOMP . CLEAN OUT BOOT BASKETS. -MILL STILL HAD LIFE BUT SHOWED WEAR, SEEN LOT OF WEAR ON WASH PIPE. DISCUSSED WITH RWO SUPT. TO CHANGE WASH PIPE AND SHORTEN LENGTH TO ALLOW LESS TORQUE AND ACHIEVE MORE WT ON BIT. -MAKE UP NEW MILL AND WASH PIPE. - RETRIEVED SMALL PIECES OF METAL FROM BOOT BASKETS. FROM INSIDE OF MILL, RETRIEVED TOP RING BELOW ELEMENT FROM THE PACKER. 01:00 - 04:30 3.50 FISH P DECOMP RIH WITH DC AND 4" DP OUT OF DERRICK TO TOP OF PACKER. -8230' 04:30 - 06:00 1.50 FISH P DECOMP OBTAIN PARAMETERS FOR MILLING PACKER. -PUW 168K -SOW 105K -FREE ROTATING WEIGHT 10K TQ - TORQUE 10 -13K , RPM 80 , WOB 10K , 4 BPM AND 350 PSI 06:00 - 07:00 1.00 FISH P DECOMP_,_ CONTINUE MILLING - PACKER RELEASED AT 0645 AND PUSHED DOWN 15' TO 8249' - ATTEMPT TO BULLHEAD BUT UNABLE - PUMPED 3.5 BBLS TO PRESSURE UP TO 3,300 PSI. -1 MINUTE BLEED TO 3,200 PSI -2 MINUTES HOLDING AT 3,200 PSI. 07:00 - 08:30 1.50 FISH P DECOMP CHASE PACKER TO 8264' AND TAG 3 TIMES. -PUMP 20 BBL HI-VIS SWEEP AT 7 BPM AND 950 PSI. - MONITOR WELL. STATIC. -BLOW DOWN KILL LINE AND TOP DRIVE. 08:30 - 11:30 3.00 FISH P DECOMP POOH FROM 8264'. 11:30 - 12:00 0.50 FISH P DECOMP FLOW CHECK AT THE BHA -L/D MILLING BHA. Printed 3/30/2011 2:31:39PM America ALASKA BP ... O itiOn Summary R p Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:00 1.00 FISH P DECOMP RIG SERVICE. - SERVICE DRAW WORKS DYNAMITIC - DRILLER CONSOL CONTROL LEAVER AND TRANSDUCER. 13:00 - 13:30 0.50 FISH P DECOMP M/U 5 -3/4" OVERSHOT TO FISH PACKER. 13:30 - 17:30 4.00 FISH P DECOMP RIH -WITH 4" DRILL PIPE TO 8100' 17:30 - 19:00 1.50 FISH P DECOMP PJSM FOR CUTTING AND SLIP OF DRILLING LINE. -CUT AND SLIP LINE. - ADJUST BRAKES. -PUMP UP DEADMAN. 19:00 - 20:00 1.00 FISH P DECOMP CONTINUE TO WASH DOWN AND TAG FISH AT 8257'. -UP WT OF 178K, DWN WT OF 108K, ROT WT OF 135K WITH 7K TQ AND 10 RPM. -OBTAIN SPRS OF 40 SPM AND 110 PSI, 30 SPM AND 70 PSI. - ROTATE OVER FISH AT 10 RPM, SEEN 80 PSI INCREASE IN PUMP PRESSURE, PU WT INCREASE OF 27K. -P/U OFF BOTTOM. 20:00 - 22:00 2.00 FISH P DECOMP CIRCULATE BOTTOMS UP WITH A SLIGHT OIL SHEEN ON BOTTOMS UP BUT NO FLOW INCREASE OR ANY OTHER INDICATIONS. 4 BPM AND 380 PSI. -PUMP SECOND BOTTOMS UP. - MONITOR WELL FOR 30 MIN. STATIC. 22:00 - 00:00 2.00 FISH P DECOMP POH WITH FISH FROM 8261' TO 6221'. ., -50K INCREASE WITH PACKER AND WORKING UP HOLE. - CONTINUOUS HOLE FILL. 3/13/2011 00:00 - 04:00 3.00 FISH P DECOMP POH FROM 6221'. - RACKING BACK DP IN DERRICK. 04:00 - 06:30 2.50 FISH P DECOMP PJSM ON PUNCHING TBG TAIL. - CHANGE OUT BLOCKS ON IRON ROUGHNECK TO PUNCH. -PUNCH TUBING ABOVE AND BELOW THE XN NIPPLE. -UD TUBING AND 7" PACKERASSEMRI Y 06:30 - 07:00 0.50 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR - PREP FOR CLEAN OUT RUN. 07:00 10:00 3.00 FISH P DECOMP PU & MU 2 -7/8" MULE SHOE, FOR REVERSE CLEAN OUT RUN. - RIH WITH (1,706') OF 2 -7/8" 6.5# EUE ON STANDS F/ DERRICK. - CHANGED OUT 5 DAMAGED 2 -7/8" JNTS 10:00 - 16:30 6.50 FISH P DECOMP CONT RIH WITH 2 -7/8" ON 4" DP FROM THE DERRICK TO THE TOP OF LINER @ 8287'. -TAG WITH 8K - CONTINUE IN HOLE INSIDE 4 -1/2" LINER -TAG UP AT 8973, BREAK CIRCULATION AT 1 BPM TO FREE UP STRING BOTTOM -@ 80 JOINTS IN TAG UP, 160K UP WEIGHT, WORK THROUGH AT 2 BPM PUMPING AT 1300 GAVE AOGCC 24 HOUR NOTICE FOR BOPE TESTING. JEFF JONES WAIVED WITNESS. Printed 3/30/2011 2:31:39PM = rrt rle ALA KA I e . e I ® 3 I 3 �: _ 7 _[[ i - �" "� a :' -'� alp ` ,� - Repr oa � �', ... .. -- , ,N .,.,.,..., 171 Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 19:00 2.50 FISH P DECOMP CONTINUE IN 4 -1/2" LINER -UP WEIGHT 165K, DOWN WEIGHT 108K, @ STAND 82 IN THE HOLE -SLOW PUMP RATES: 2.5 BPM @ 220 PSI, 3.3 BPM @ 410 PSI -HARD TAG TOP OF SAND AT 9580' - ATTEMPT TO RECIPROCATE PIPE TO MAKE HOLE WHILE PUMPING 3.3 BPM AT 700 PSI -OVERPULLS TO 175K INDICATE DEBRIS COMING LIP AROUND 2 -7/8" COLLAR -POOH TO ABOVE LINER TOP STANDING BACK DP, CALL RWO SUPT, ANCHORAGE ENGINEER FOR PLAN FORWARD. 19:00 - 21:00 2.00 FISH P DECOMP CIRCULATE BOTTOMS UP AT 7 BPM AND 980 PSI. -SEEN SMALL OIL SHEEN ON BOTTOMS UP. -PUMP SECOND BOTTOMS UP AT 7 BPM AND 980 PSI. - MONITOR WELL FOR 30 MIN. STATIC 21:00 - 00:00 3.00 FISH "P DECOMP POH FOR BHA CHANGE. -POH TO CHANGE BI-IA TO 3 -7/8" JUNK MILL WITH BOOT BASKETS AND JARS. 3/14/2011 00:00 - 01:30 1.50 FISH P DECOMP POH FOR BHA CHANGE. -POH TO CHANGE BHA TO 3 -7/8" JUNK MILL WITH BOOT BASKETS AND JARS. -LARGE SCRAPES IN MULE SHOE JOINT RIGHT BELOW COLLAR FROM WHAT HAD US HUNG UP. 01:30 - 02:30 1.00 FISH P DECOMP CLEAN AND CLEAR RIG FLOOR. -R/U TO RUN 2 -7/8" PAC. - CHANGE OUT HANDLING EQUIPMENT. -P /U NEW BHA TOOLS. 02:30 - 10:00 7.50 FISH P DECOMP M/U 3 -7/8" JUNK MILL. -P /U 2 -7/8" PAC PIPE FROM SHED 1 X 1 TO 1708'. 10:00 - 10:30 0.50 FISH P DECOMP ESTABLISH MILLING PARAMETERS -PUMP 7 BPM @ 2840 PSI -PUW 185K, SOW 11 OK -FREE TQ @ 40 RPM = 9.5K SLOW PUMP RATES -300 PSI @ 2 BPM -60 PSI @ 1 BPM TAG TOP OF FRAC SAND © 9577' MD Printed 3/30/2011 2:31:39PM America'_.. ALASKA , € g O oft Op turn Summary Report � € Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 - 13:00 2.50 FISH P DECOMP BEGIN MILLING WHILE PUMPING 7 BPM DOWN THE DRILL PIPE -MILL DOWN AT 40 RPM, 7 BPM @ 2940 PSI, TORQUE 9.5 -11 K, WOB 0 -5K - OCCASIONAL BITES ON DEBRIS WITH INCREASED TORQUE TO STALL AT 11K -PUMP 2 HI-VIS 20 BBL SWEEPS PER STAND, RECIPROCATING PIPE AS SWEEP COMES UP BACKSIDE - CARBOLITE AND A FEW SMALL ELEMENT PIECES IN RETURNS -WELL STARTED TAKING FLUID AT 11:00 - 9620' MD WITH INITIAL LOSS RATE OF 48 BPH PUMP ON BRING DOWN PUMP TO 2 BPM TO FIND LOW PUMP RATE LOSSES -0 BPH LOSSES AT 2 BPM -ONCE PUMPING DYNAMIC LOSSES OF 32 BPH 13:00 - 21:30 8.50 FISH P DECOMP CONTINUE MILLING AT 40 RPM, 7 BPM @ 2760 PSI, TQ 9 -11 K, WOB 0 -5K - OVERPULLS TWICE TO 50K, INDICATING DEBRIS COMING UP ALONG SIDE PIPE AT 9720' -PUMP 2 HI-VIS SWEEPS PER STAND, SAND IN RETURNS - LOSSES 30 BPH MU SINGLE TO TARGET DEPTH OF 9900' -PUMP 2 HI-VIS 20 BBL SWEEPS - SHUTDOWN PUMP TO MONITOR WELL BEFORE COMING OFF BOTTOM. WELL STATIC. -POH 18 STANDS TO GET OUT OF LINER TOP. - ESTABLISH DYNAMIC LOSS RATE OF 84 BPH DURING BEGINING OF CIRCULATION AT 8.5 BPM AND 2550 PSI. LOSS RATE STOPPED PRIOR TO SHUTTING DOWN PUMPS. PUMPED A TOTAL OF 2 B /U. -PUMP 20 BBL HI-VIS SWEEPS WITH SAND IN RETURNS - STATIC LOSS RATE DURING MONITORING OF WELL FOR 30 MIN. STATIC LOSS RATE BUT DURING MONITORING OF WELL THE FLUID LEVEL FELL ABOUT 2'. 21:30 - 00:00 2.50 FISH P DECOMP PJSM FOR POOH UD DP. -POH LAYING DOWN DP IN PIPE SHED. FROM 8147' TO 6267'. -LOSS RATE INCREASED TO 5 BPH. 3/15/2011 00:00 - 01:00 1.00 FISH P DECOMP RIG SERVICE. - INSPECT TOP DRIVE. 01:00 - 09:00 8.00 FISH P DECOMP POH UD DP IN PIPE SHED. -LD PIPE FROM 6267' TO DC. - MAINTAIN CONTINUOUS HOLE FILL. 5 BPH LOSS RATE. Printed 3/30/2011 2:31:39PM " dierth America - 111 •f 134 E.. Operation oum.474 Repo) , Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 13:30 4.50 FISH P DECOMP LD BHA, COLLARS, JARS BOOT BASKETS - RECOVERED 4 SMALL PIECES OF THIN METAL FROM THE BOOT BASKETS, LOOKED TO BE PIECES OF PACKER. - MILL WAS HEAVILY WORN ON THE FACE AND THE SIDES, LOOKS LIKE WE WERE MILLING SOME PACKER SLIPS AT SOME POINT. 13:30 - 14:30 1.00 FISH P DECOMP CLEAN & CLEAR RIG FLOOR AND PIPE SHED. -RU BOPE TESTING EQUIPMENT 14:30 - 21:30 7.00 BOPSUR P DECOMP PJSM FOR BOPE TESTING OPERATIONS - CONTINUOUS HOLE FILL MAINTAINED DURING BOPE TESTING - WEEKLY BOPE TESTING. TEST BOPE: -TEST 2-7/8" TIW VALVES, DART VALVES. -TEST RAMS W/ 2- 7 /8'TEST JTS. bOP -TEST ANNULAR W/ 2-7/8" TEST JT. -TEST TO: 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES. -DRAW DOWN TEST - SYSTEM PSI OF 2950, PSI AFTER CLOSE OF 1800, 200 PSI ATTAINED IN 17 SEC, FULL PSI ATTAINED IN 77 SEC., 5 BOTTLES AT 2000 PSI. -ALL TEST GOOD. - AOGCC, JEFF JONES, WAIVED WITNESS. -ALL TESTS WITNESSED BY BP WSL & DDI TP. - SPOTTED THE SPOOLER -R /D ALL TEST EQUIPMENT. 21:30 - 00:00 2.50 RUNCOM P RUNCMP GATHER UP CENTRILIFT EQUIPMENT. -PJSM ON R/U SHEAVE. - GATHER CLAMPS. -HANG SHEAVE. -HAVE CENTRILIFT HAND GIVE CLASS TO CREW GOING OFF TOUR ON HOW AN ESP PUMP AND COMPONENTS WORK. - CONTINUOUS HOLE FILL WITH 5 BPH LOSS RATE. 3/16/2011 00:00 - 00:30 0.50 RUNCOM P RUNCMP HOLD CLASS ON HOW ESP PUMP WORKS WITH CREW COMING ON TOUR AND THE CENTRILIFT HAND. - CONTINUE TO R/U TO RUN ESP. 00:30 - 04:00 3.50 RUNCOM P RUNCMP P/U AND M/U MOTOR SECTIONS OF ESP. P - CENTRILIFT CREW TIES IN MOTOR SECTIONS. - FILLING WITH LUBRICANT AS P /U. -PULL UP CONTROL LINE AND TIE INTO MOTOR. 04:00 - 06:00 2.00 RUNCOM P RUNCMP RIH WITH ESP COMPLETION ON 2 -7/8" 6.5# TUBING EUE 8 RD. -P /U 10' PUP JOINT. -P /U 1 JOINT 2 -7/8" TUBING. -P /U 2 -7/8" XN- NIPPLE. -P /U 10' PUP JOINT. -RIH WITH 1 STAND 2 -7/8" TUBING. -RIH WITH DUMMY GLM. - MAINTAIN CONTINUOUS HOLE FILL WITH 3 -5 BPH LOSS RATE. Printed 3/30/2011 2:31:39PM n Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7/1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 16:00 10.00 RUNCOM P RUNCMP RIH W/ 2 7/8" EUE 8 RND ESP COMPLETION, RUNNING 75 STANDS OUT OF DERRICK. - USING BEST 0 LIFE 2000 PIPE DOPE, TORQUE TUBING TO 2300 FT /LBS. - CHECKING CONDUCTIVITY AND PUMPING 10 BBLS DOWN TUBING EVERY — 2000' 2 BPM @ 1020 PSI , --60 STANDS MAINTAINING CONT HOLE FILL DURING TRIP IN HOLE WELL ON LOSSES,AVG STATIC LOSS RATE - -1.5 -2 BPH FIELD VISIT FROM GREG MATTSON, STEVE ROSSBEFRG & HERB WILLIAMS 16:00 - 19:30 3.50 RUNCOM P RUNCMP REEL TO REEL SPLICE. - SPLICE OPERATION PERFORMED BY CENTRILIFT REP. - CONT HOLE FILL WAS MAINTAINED FOR WELL CONTROL DURING SPLICE OPERATIONS AT 2 BPH LOSS RATE. - HAD TO SWAP OUT THE NEW REEL, THE ARMOR WAS BAD. -HELD UNANNOUNCED WELL CONTROL DRILL. -HELD AAR ON DRILL. -AAR REVEALED THAT THE SET UP WE HAD ON THE FLOOR FOR THE TIW WAS NOT THE MOST EFFICIENT FORA WELL CONTROL SITUATION. AFTER THE DRILL THE CREW AND TOOL PUSHER REVISED THE SET UP TO BETTER ACCOMIDATE HAVING TO DEAL WITH CUTTING AN ESP CABLE. 19:30 - 22:30 3.00 RUNCOM P RUNCMP CONTINUE TO RIH WITH 2 -7/8" EUE 8 RND COMPLETION. -RIH TO 8163'. - MAINTAIN CONTINUOUS HOLE FILL WITH 2 BPH LOSS RATE. -UP WEIGHT OF 92K, DOWN WEIGHT OF 70K. -USED 133 EACH LESALL CLAMPS, 3 FLATGUARDS, AND 6 PROTECTERLIZERS. 22:30 - 23:00 0.50 RUNCOM P RUNCMP BREAK CIRCULATION. -PUMP TUBING VOLUME AT 2 BPM AND 960 PSI. -B /0 AND BLOW DOWN CEMENT LINE. 23:00 - 00:00 1.00 RUNCOM P RUNCMP PJSM: PICK UP AND MAKE UP TUBING HANGER AND LANDING JOINT. -MU LOWER CONNECTOR & PENETRATOR IN TBG HANGER. 3/17/2011 00:00 - 02:00 2.00 RUNCOM P RUNCMP CONTINUE TO MU LOWER CONNECTOR & PENETRATOR IN TBG HANGER. -TEST SPLICE. 02:00 - 03:00 1.00 RUNCOM P RUNCMP LAND TUBING HANGER AND 2 -7/8" ESP, COMPLETION. RUN IN LOCK DOWN SCREWS. -253 JOINTS OF 2 -7/8" TUBING, MU TORQUE = 2,300 FT -LBS. -PU WT = 92K LBS, SO WT = 70K LBS. -133 LASALLE CLAMPS, 3 FLAT GUARDS, AND 6 PROTECTOLIZERS Printed 3/30/2011 2:31:39PM rw ae. titS 11 nary Repo Common Well Name: MPC -22 AFE No Event Type: WORKOVER (WO) Start Date: 3/6/2011 End Date: 3/17/2011 X4- 00T4Q -E (670,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 7 /1/1994 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292248900 Active Datum: 44 : 22 10/27/1998 14:00 @39.80ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 06:00 3.00 BOPSUR P RUNCMP INSTALL TWC. -TEST TWC FROM BELOW TO 500 PSI ROLLING. GOOD TEST. CHARTED FOR 10 MIN. -PUMP AT 6 SPM AND 7 BBLS FOR A 10 MIN. ROLLING TEST. -ATTEMPT TO TEST TWC TO 3500 PSI FROM ABOVE. -P /U 2 -7/8" LANDING JOINT AND INSTALL. RETEST TWC TO 3500 PSI. FAILED DUE TO LEAK IN JOINT CONNECTION. -P /U SECOND LANDING JOINT. RETEST TWC TO 3500 PSI FOR 10 MIN CHARTED. GOOD TEST. -RID LANDING JOINT AND TEST EQUIPMENT. 06:00 - 11:00 5.00 BOPSUR P RUNCMP BLEED DOWN LINES AND STACK -ND 13-5/8" ANNULAR PREVENTER "GK" BOP PULL BLIND /SHEAR RAMS OUT SO THEY CAN BE RECONFIGURED IN THE DOUBLE GATE FOR-THE 4 PREVENTER STACK - PULLED 2 -7/8"" BY 5" VBRS OUT AND INSTALLED SOLID BODY 2 -7/8" PIPE RAMS IN PREPARTION FOR THE 4 PREVENTER -STACK ON NEXT WELL. - CLEANING PITS 11:00 - 14:30 3.50 WHSUR P RUNCMP NIPPLE UP TUBING HEAD ADAPTOR PER FMC - ORIENT TREE - SURFACE TEST OF ESP CABLE BY CENTRILIFT, GOOD TEST -FMC REP TO TEST TUBING HEAD ADAPTER TO 250 PSI LOW, 5000 PSI HIGH FOR 5 CHARTED MIN GOOD TEST. - CENTRILIFT PERFORMED FINAL CHECKS. -BHP = 2751 PSI, MOTOR TEMP = 136.2F, INTAKE TEMP = 134.4F -2.9 PHASE TO PHASE, 1.4 GIG OMS PHASE TO GROUND. 14:30 - 17:00 2.50 WHSUR P RUNCMP NU TREE - PRESSURE TEST TO 250 PSI LOW AND 5000 PSI HIGH FOR 5 CHARTED MIN - CLEANING PITS,MORE THAN NORMAL AMOUNTS OF FRAC SAND IN THE PITS FROM CLEAN OUT 17:00 - 00:00 7.00 WHSUR P RUNCMP PJSM: LAY DOWN 24 STANDS OF 4" DP IN THE DERRICK THAT WAS USED FOR SUPPORT WHILE PULLING THE 2 -7/8" TUBING - SECURE WELL AND CELLAR Printed 3/30/2011 2:31:39PM • • Page 1 of 1 Regg, James B (DOA) From: Sarber, Greg J [SarberJG @BP.com] Sent: Saturday, March 12, 2011 2:24 PM To: DOA AOGCC Prudhoe Bay Cc: Ciolkosz, Ryan R; Bjork, David; Smart, John C; Rossberg, R Steven; Cismoski, Doug A; Engel, Harry R; Daniel, Ryan; Kilfoyle, Jeffery A Subject: BOP Usage on Doyon 16, 3 -11 -2011 Follow Up Flag: Follow up Flag Status: Red Attachments: BOPE usage 3 -11 -2011 .doc All, The BOP on Doyon 16 was used on 3 -11 -2011 to circulate out produced fluids trapped under a packer. The complete 1 page description is attached to this email. Please contact me should you need additional informaiton. Thank you, Greg Greg Sarber Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) +1 (907) 242 -8000 (Cell Phone) Harmony2157 r> MI Jim Willingham • 3/15/2011 • • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of anv BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Welisite Leader Name: David Rhodes Contact Number: 659 -5329 Contact Number: 659 -4177 Traction Number: Well Location & Name: MPC -22a Permit To Drill (PTD) Number: -50•6 •- 2489 -01 Date and Time of Incident: March 11, 2011 00:00 -19:00 hrs Original Scope of Work: The rig was conducting a work over tubing swap in the Milne Point field. At the time of the incident they were milling to release the 7" Packer /Tail pipe assembly with plug set in the in `XN' nipple at 8,266' md. Operational Description Leading up to Well Control Event: As the Packer was being milled, communication was established with the trapped Packer fluids below the packer. Prior to milling, the driller was warned of the possibility that there were trapped well bore fluids trapped below the packer. The driller had milled about 6" of the packer and got an indication that the packer integrity was lost and there was a possible flow from the well. The Driller shut the well in and attempted to Bull Head any produced fluids below the packer back into the perforations. There was no injectivity into the perforations. BOPE Used and Reason: The Driller observed a slight increase in return flow and the Annular Preventor was shut -in with `0' psi on drill pipe and annulus. Attempted Bull Head operation failed. The was checked for flow. There was no flow. Bottoms up was circulated though the Gas Buster. During circulation, there was communication established thru the packer and the crude oil trapped under the packer did swap out with the brine being used to perform the workover. There was a small amount of crude oil ( -30 bbl) that was circulated to surface. At no time was there any pit gain or pressure observed on the wellhead. After several hours of circulation allowing the crude under the packer to bubble out, the crude stopped and the well was monitored for flow again. The well was monitored static. The BHA was tripped out of the hole for a new mill. Milling operations continued, the packer was released and pushed to bottom. There have been no additional signs of any well bore fluid, flow, or pit gain. Is a BOPE Test Required after use ( Yes / No): If no, why? No, because no Well bore pressure was contained by the BOPE and the annular preventer was not shut in on wellbore fluids. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: Continue with workover operations on this well. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayalaska.gov Email CC List BP WSL Harry Engel Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer- Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC August 2, 2010 HRE 1 STATE OF ALASKA ,, ALASKA AND GAS CONSERVATION COMMISSI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ~ FRACTURING Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ ~ 195-1980 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22489-01-00 8. Property Designation (Lease Number) : 9. Well Name and Number: , ADLO-047437 MPC-22A 10. Field/Pool(s): MILNE PO INT FIELD / KUPARUK RIVER OIL POOL 11. Present Well Condition Summary: Total Depth measured 9995 feet Plugs (measured) None feet true vertical 7254.25 feet Junk (measured) None feet Effective Depth measured 7705 feet Packer (measured) 8240 true vertical 7171 feet (true vertical) 5704 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# H-40 SURFACE - 112 SURFACE - 112 1530 520 Surface 6685 9-5/8" 40# L-80 SURFACE - 6715 SURFACE - 4756 5750 3090 Intermediate Production 8408 7" 26# L-80 SURFACE -8435 SURFACE - 5847 7240 5410 Liner 1729 4-1/2" 12.6# L-80 8266 - 9995 5722 - 7254 8430 7500 Liner Perforation depth: Measured depth: O 9610 - 9632 O 9636 - 9666 O 9666 - 9692 True Vertical depth: 6896.9 - 6917.18 6920.87 - 6948.58 6948.58 - 6972.65 _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 SURFACE - 8279 SURFACE - 5732 Packers and SSSV (type, measured and true vertical depth) T_X 4.5" BAKER - FR 8240 5704 gip., , ~~~~Q 12. Stimulation or cement squeeze summary: ~-.:,`~ ,~ ~ (~ Intervals treated (measured): IS4 tt 33rr ~ ~~~/ ~1t. (~~j'~q }~p~q(~ ~5 A!~~ L"Fr a..ti ~iY! ~iI RF§I.^S~f ~L7!'7A II~SSI~Ii Treatment descriptions including volumes used and final pressure: .~ 41C0a.~f1~l~r''. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 149 377 370 202 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ~ Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signature QUu eZ one 564-4944 Date 8/26/2010 VI111 IV-YVY fJfG VIJGV //GVV~7 ®['~~ hA Vu Vlllll VII IIIQI Vlllr \J MPC-22A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 8/16/2010 ***SLB Frac Crew"*" Job Scope: Fracture Targeted A2/A3 Kuparuk Sands ~ ~«<InterAct Publishing»> Rig up frac equipment and tree saver. Pump break :,down/step down test, Scour Stage, Data Frac. Pump Frac at 15 bpm using 20# x-link gel w. 7 gpt of L065 (Scale Inhibitor). Pump 300 bbl pad then pump 100 j bbls of 1 ppa stage leading in with 20/40 ceramic proppant. Ramp to 4 ppa run ~ 'out 20/40 prop and switch to 16/20 ceramic proppant. Hold 4 ppa flat stage for ~ 100 bbls, no increase in treating pressure with 4 ppa top to bottom, treating pressure - 5400 psi. Ramp to 10 ppa in 250 bbls, treating pressure - 5800 psi. E 3Screened out with 10 ppa on perfs. Total~roo behind nine 98500#. Left E22500# prop in pipe. "**Job Complete'`*" FLUIDS PUMPED BBLS 1148 YF125ST 13500# 20/40 CERAMIC PROPPANT 107500# 16/40 CERAMIC PROPPANT 305 20# LINEAR GEL 65 X-LINK 100 1 PPA 1618 Total Tree:3 1/8 "- 5M FMC Wellhead: 13 5/8" 5M FMC 13" X 3.5" FMC tubing hanger CIW 3.5" H BPV profile. 20" 94 ppf, H-40 BTC 112' KOP @ 500' Max. hole angle = 53-55 deg @ 2650 - 7300' Hole angle thru perfs = 23 deg 9 5/8", 40 ppf, L-80 6715' Btrc. 2 7/8", 6.5#, L-80 8rd. eue (drift ID = 2.347", cap. _ .0058 bpf) MPC-22A Orig. RT Ele~6' (N 22E) Orig. GL Ele . 17.4` ~~~T RT to 7' Hgr = 30.12 (N 22E) Camco glm. kbmm. w/ bk latch and ' d 5 2478' _ 2247' 48 4 4680' 3548' 54 3 6260' 4492' 54 2 7459' 5194' 52 1 8180' 5664' 47 7" 26 ppf, L-80, Btrc. prod. casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) Note: PDS centralizer arm was lost during the caliper survey on 6/6/10. ~' USE EXTREMF_ CAUTION when running tools ' below the WLEG. Stimulation Summary 12/28/95 - 91.25M Ibs of 20-40 carbolite behind pipe. Kup 'A' sand job went to flush. HES 2 7!8" X-Nipple (2.313" id) 8228' Perforation Summary Ref log: 12/23/96 DIL / GR 7 x 4.5" Baker S-3 Perm Pkr. 8240' HES 2 718" XN-Nipple (2.313" id) 8266' KUP 'B' Sand (2.205" min id) 2 1/2 4 9610' - 9632' (6897'-6918') WLEG 8278' SUP 'A' Sand ' ' ` ' 8266' ) o ~ 2 1 /2 4 9636 (6921 -6949 - 9666 Baker ZXP liner top packer 3 3/8 6 9666' - 9692 (6949'-6973`) °j ~ " Baker 4.5" HMC liner hanger 8281' L~ Liner 4.5" 12.6 ppf, L-80, NSCT 21/2 guns loaded w/ 10.5 gm jumbo jet charge (ID = 3.958", Cap. _ .0152 bpf) (EHD = 0.52", TTP = 6.8") w/ 90 deg phasing Top of window 8435' and ~ 3 3/8" gun loaded w/ 22 gm jumbo jet charges ` ~ (EHD = 0.76", TTP = 6.4") w/ 60 deg phasing y Original Hole Fill tagged at 9885' wlm on 12/26/9 4 1/2" float collar (PBTD) 9904' 41/2" float shoe 9995' DATE REV. BY COMMENTS MILNE POINT UNiT 12/31/95 JBF Wellbore sidetracked by Nabors 4ES WELL C-22A 8/22/98 MDO ESP RWO by Nabors 4ES API NO: 50-029-22489-1 10/31/98 Linder M RWO by Nabors 4ES . 9/23/02 L. Hulme Convert to Gas Lift Well (Nabors 4ES) gp EXPLORATION AK Alaska Data 8 Consulting Services 2525 Gambell Street, Sude 400 Anchorage, AK 99503-2839 - >>", Sc6~6er~r Alaska Data & Consulting Services 2525 Gembell Street, SuKe 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job M 0?/1 A/ t D NO. 5473 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Log Description Date BL Color CD MPC-22A F-21 BAUJ-00007 AYKP-00073 MEM PROD PROFILE W/GLS PROD PROFILE - 2/11/10 02/16/10 1 1 1 1 13-17 AYKP-00072 INJECTK)N PROFILE 02/14/10 1 1 P2-48 AVYO-00057 PROD PROFILE 02/11/10 1 1 16-01 BBSK-00006 USIT 02/11/10 1 1 MPC-24A V-224PB1 BAUJ-00005 08AKA0147 MCNL OH MWD/LWD EDIT 01/09/10 11/26/09 1 2 1 1 YLCN,c AliR1VVYYLCVtac Ht:liCiY1 Cr Dlurvmu rarvu nc ~unrvnvV urvc a.vrt cn~.n ,v. BP Explo2tion (Alaska) Inc. Petrotechnical Data Center LR2-t 900 E. Benson Blvd. ~chlum~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 NTTN: Beth Well Job q ~~pA h NO. 5481 s ipti,~s.~~ ~Vl~~ 4 ,F. ~~,rC .. ., y.. ,. w..~.-.. ~-- Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color rn U-10 83S0-00048 CROSSFLOW DETECT/IBP __ C-13A AVYO-00060 CBL - C 03/02/10 1 1 _,__ AGI-01A AVYO-00056 USIT _ 02/16/10 1 1 03-37 BBSS-00002 SONIC SCANNE 02/10!10 1 1 _ 03-37 BBSS-00002 R-MSIP ~' SS-ANALYSIS BEHIND CSG 02/14/10 1 1 _____ 07-21 B3S0-00045 . SPINNER LOG/PRE-IBP L L 02/14/10 i 1 P2-48 AVYO-00057 PROD PROFILE REDO 02/24/10 1 1 AGI-01A B9RH-00014 JEWELRY LOG W/PRESS/TEMP 02/11/10 1 1 W-204 B14B-00097 GLS (3 - ~ 02/27/10 1 1 09-41 BBSK-00010 CROSSFLOW RECORD 03/01/10 1 1 _ 15-27 BBUO-00006 ~ RST GRAVEL PACK 03/06/10 1 1 15-27 BBUO-00006 LDL _ 03/05/10 03/05/1 1 1 MPC-22A 05-08 BAUJ-00007 BBSK-00001 MEM PPRO W/GLS REVISED RST ~ ~ 0 02/11/10 1 1 1 1 D-048 E-198 10715393 11767134 - ' ~- MCNL REVISED ~ ~ MCNL REVISED - 01/17/10 04!07/04 1 1 1 1 16-30A 82NJ-00052 MCNL _ ~ ~ 07/21/07 1 _ W-56 09AKA0186 OH MWD/LWD EDIT ._ - ~ 01/31/10 1 1 12/19/09 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: Petn,teclinical Data Center LR2-t Alaska Data & Consulting Services J00 E. Benson Blvd. 2525 Gambell Street, SuAe 400 Anchorage, AK 99503-2838 1~ 03!10/10 ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE - 39.4' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 582' NSL, 2054' WEL, SEC. 10, T13N, R10E MPC-22A At top of productive interval 9. Permit Number / Approval No. 195-198 836' NSL, 4047' WEL, SEC. 14, T13N, R10E 10. APl Number At effective depth 50-029-22489-01 744' NSL, 3988' WEL, SEC. 14, T13N, R10E 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 713' NSL, 3975' WEL, SEC. 14, T13N, R10E Sands 12. Present well condition summary Total depth: measured 9995 feet Plugs (measured) true vertical 7254 feet Effective depth: measured 9905 feet Junk (measured) true vertical 7171 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface 6685' 9-5/8" 1300 sx PF 'E', 250 sx Class 'G' 6715' 4756' Intermediate Production 8408' 7" 150 sx Class 'G' 8435' 5847' Liner 1729' 4-1/2" 200 sx Class 'G' 8266' - 9995' 5722' - 7254' Perforation depth: measured 9610'- 9632', 9636'- 9666', 9666'- 9692' true vertical 6897' - 6918', 6921' - 6949', 6949' - 6973' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 8279' Packers and SSSV (type and measured depth) 7" x 4-1/2" Baker S-3 Hydro Set packer at 8240'. R~C~iVED 13. Stimulation or cement squeeze summary LOCT 0 Intervals treated (measured) ,~aska 0ii.& Gas ~-0ns. C0mmis~i0~-: Treatment description including volumes used and final pressure Anch0ra~e 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is trueand correct to the best of my knowledge Signed Sondr ' ~ ~' -"v-'--~_ ~'ritle Technical Assistant Date I L~.; ' L~ ~' (~;' ~-- Prepared By Name/Number: Sondra Stewman, 564-4750 . . Form 10-404 Rev. 06/15/88 Submit In Duplica~e.e...~ Legal Well Name: MPC-22a Common Well Name: MPC-22a Spud Date: 7/1/1994 Event Name: RECOMPLETION Start: 9/21/2002 End: 9/23/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/23/2002 Rig Name: NABORS 4ES Rig Number: 4 I'::B~rs: : i Description of Operations i 9/20/2002 15:00 - 22:00 7.00 MOB P I PRE MI/RU NABORS 4ES (RIG ACCEPT @ 2200 HRS. 9/20/2002 22:00 - 00:00 2.00 KILL PI DECOMP RIG UP LINES TO TIGER TANK ETC. 9/21/2002 00:00 ~ 04:00 4.00 KILL N WAIT DECOMP WAIT ON AVAILABILITY OF TRUCKS TO HAUL BRINE FOR WELL KILL 04:00- 06:00 2.00 KILL N WAIT DECOMP UNLOAD BRINE 06:00 - 13:00 7.00 KILL P DECOMP A-I-I-EMPT TO BLEED GAS TO TIGER TANK & CHOKES KEPT FREEZING OFF & BULLHEADING WAS ACCEPTED I AS THE BEST WAY TO ACCOMPLISH THE WELL KILL & I THIS WAS DONE WITH 10.2 PPG. BRINE. INITIAL I STARTING TBG. PSI. 2700 PSI. ANNULUS=3000 PSI. AFTER WELL KILL SITP=70 PSI. SlCP=70 PSI. 13:00-16:30I 3.50 KILL P DECOMP /BUILDV~rTO10.5PPG.&ClRCBRINE@4-BPM & MONITOR WELL BORE & CACULATE FLOW BACK, WELL I CONTINUE TO FLOW AND NO DECREASE IN MEASURED FLOW BACK WAS DETECTED AFTER 30-MIN OF i MONITOR. 16:30-19:00 2.50 KILL P DECOMP BUILD BRINE WT. TO10.TPPG.&ClRCSAMEAROUND& MONITOR WELL (STATIC) 19:00 - 19:30 0.50 WHSUR P DECOMP SET & TEST TWC 19:30 20:30 1.00 WHSUR P ~DECOMP NIPPLE DN TREE 20:30 - 22:30 2.00 BOPSURP DECOMP ]NIPPLE UP BOP TEST BOP TO 250 /3500 (TEST WAIVED BY JEFF JONES 22:30 00:00 1.50 BOPSUI~P !DECOMP W/ AOGC) [ DECOMP 9/22/2002 100:00 - 01:30 1.50 BOPSUF~ P ' TEST BOP TO 250/3500 (TEST WAIVED BY JEFF JONES ' : WITH AOGC) I 01:30- 02:30 1.00 PULL P I i DECOMP RIG LUBRICATOR & PULL TWC 02:30 03:00 0.50 PULLP J i DECOMP MU LANDING JT. & PULL HANGER TO FLOOR & TEST ESP I CABLE. 03:00 - 07:30 4.50 PULL P DECOMP POOH WITH ESP COMPLETION 07:30 - 10:00 2.50 PULL P DECOMP LAY DN ESP ASSY. & CLN-FLOOR 10:00 - 13:30 3.50 CLEAN P DECOMP MU SCRAPER & RIH TO (8274' 4ES KB) 13:30 - 17:30 4.00 CLEAN P DECOMP POOH & LAY DN SCRAPER & (CLN-RIG FLOOR FOR I , COMPLETION RUN) 17:30 - 23:00 5.50 RUNCOI~I~ COMP MU PACKER & TAILPIPE & RIH WITH GAS LIFT COMPLETION & SPACE OUT & LAND HANGER. & RILDS 23:00 - 00:00 1.00 BOPSUF; P COMP SET TWC & TEST & NIPPLE DN BOP 912312002 00:00 - 00:30 0.50 BOPSUF P COMP NIPPLE DN BOP 00:30 - 02:00 1.50 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. 02:00 - 02:30 0.50 WHSUR P COMP PULL TWO 02:30 - 04:30 2.00 RUNCOI~!~ COMP DROP SETTING BALL & PRESSURE TBG. TO 3500 PSI. & MONITOR FOR 30-MIN & BLEED TBG. TO 1500 PSI. & PRESSURE ANNULUS TO 3500 PSI. & CHART FOR 30- MIN · & BLEED TBG. & SHEAR RP IN LOWER GLM. 04:30 - 05:30 1.001RUNCOI~P COMP RIG HB&R & REVERSE CIRC. 70 BBL. DIESEL DN ~i COMP ANNULUS TAKING RETURNS THROUGH TBG. & U-TUBE i TO TBG FOR FREEZE PROTECTION. ' SET BPV & SECURE TREE AREA. (RIG RELEASED @ 0600 05:30 - 06:00 I 0.50 WHSUR i P I HRS. 9/23/2002) : I I . Printed: 9~25~2002 4:09:09 PM bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 10, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for MPC-22A --- Change out ESP and replace it with Gas Lift. BP Exploration Alaska, Inc. proposes to convert well MPC-22a from a failed ESP producer to a Gas Lifted producer as part of the Milne Point Kuparuk Water / MI Flood Development project. MPC-22 was drilled and completed in 1994 and a sidetrack was completed in 1995 after an ESP was sanded up in the whole. The well has had three ESP completions installed with the longest run life, coming from the last pump installed, was around 3 years. The failure mechanism is believed to be related to the rising GOR in the well, currently around 1300-2000.'"'With the GOR at its current level and expected to rise farther it will be difficult enviroment for maintaining ESP's and is much more suitable to Gas Lift. /'' A RWO is planned for around the 18th of September to pull the failed ESP and install a gas lift string and all required surface facilities. Please see attachments for diagrams of the current and proposed wellbore diagrams. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5943 or e-mail me at AivanoMJ@bp.com. Michael Aivano Milne Point Unit Petroleum Engineer SCANNED OCT 0 4 2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1"."'Type of request: Temp Abandon_ Suspend_ ' ' Operational shutdown _ Reenter suspended well _ ESP Change to Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Gas Lift Change approved program _ Pull tubing _X Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Bp Exploration (Alaska), Inc. Development__X RKB 25.8 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 196612 Stratigraphic __ Anchorage, AK 99519-6612 Service__ Milne Point Unit 4. Location of well at surface 8. Well number 4698' FNL, 2054' FEL, Sec. 10, T13N, R10E, UM (asp's 558411, 6028866) MPC-22A At top of productive interval 9. Permit number / approval number 4438' FNL,'4042' FEL, Sec. 14, T13N, R10E, UM (asp's 561750, 6023872) 195-198 At effective depth 10. APl number 4535' FNL, 3988' FEL, Sec. 14, T13N, R10E, UM (asp's 561805, 6023776) 50-029-22489-01 At total depth 11. Field / Pool 4566' FNL, 3975' FEL, Sec 14 T13N, R10E, UM (asp's 561819, 6023745) Miline Point Unit / Kuparuk River Pool 12. Present well condition summary Total depth: measured 9995 feet Plugs (measured) true vertical 7254 feet Effective depth: measured 9904 feet Junk (measured) true vertical 7170 feet Casing Length SiZe Cemented Measured Depth True vertical Depth Conductor 80' 20" 250 sx Arcticset 1 (approx) 112' 112' Surface 6685' 9-5/8" 1300 sx PF 'E', 250 sx Class 6715' 4756' 'G' Intermediate 8408' 7" 150 sx Class 'G' 8435' 5847' Liner 1729' 4-1/2" 200 sx Class 'G' 8266' - 9995' 8722'- 7254' Perforation depth: measured Open Perfs 9610'-9632', 9636'-9666', 9666'-9692' true vertical Open Perfs 6897'-6918', 6921'-6949', 6949'-6973' Tubing (size, grade, and measured depth 2-7/8" 6.5# L-80 to 8105'. ESP @ 8156'. Packers & SSSV (type & measured depth) No Packers. 2-7/8" Camco KBMM GLM @ 116'. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: September 23, 2002 16. If proposal was verbally approved Oil X Gas __ Suspended _ Name of approver / _~~~ _D,~proved Service. 17. I hereby certify t~ and cor~f my knowledge. Questions? Call Michael Aivano @ 564-5943. Signed ~/~~~ ~% Milne Petroleum Fn§ineer DateeeptemberlO, 2002 Michael ~¥ano [ [~ ..... ~ ~roparod by DoWayno FI. Schnorr 5~4-5174 -- FOR CO~MI$$1ON USE O~1,¥ Conditions of approval: Notify Commission so representative may witness I Approval no. Mechanical Integrity Test_ Subsequent form required 10- Approved by orde_r o_f t.he _C_o.m_m_issi_on_ ,__ /'t. ammv ~_~li Tavlr~~ Commissioner Date ANNbL 0 & ZOOZ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 2 7/8" Camco KBMM 8028' GLM (wI 1" sìdepocket) 2-7/8" 6.5 ppf, L-80 8rd EUE tbg. HES XN-Nipple (2.205 íd) I 8055' (Orift=2.347", Cap.=.0058 bpf 7" 26 ppf, L-80 Btrc. production Centrìlift GC 1150 ESP, casing 8105' ( 10 = 6.276", cap. = 0.0383 bpf) series 562, GPMTAR,1:1 159 Stg. TVO Intake 5,632' Centrilift Tandem Gas 8123' I Seperator GRSTXBAR6 Centrìlift I GST30BHLPFS 8128' Centrilift KMH 512 Series, I 114 hp. motor, 2330v./ ~~O amp. 8140' seal section I 8156' I Phoenix Sensor Tree: 3 1/8" - 5M WKM{ Wellhead: 135/8" 5M F~. Tbg. Hng: 13" x 3.5" FMC 20" 94 ppf, H-40, Btrc. I 112' KOP @ 500' Max. hole angle = 53 to 55 deg. fl 2650' to 7300' Hole angle across perforations = 22.5 deg. 9 5/8", 40 ppf, L-80 Btr9' 6715' I Stimulation Summary 12/28/95 - 91.25M Ibs of 20-40 carbolite behind pipe, Kup 'A' Sand, job went to flush. Perforation Summary Ref loa: 12/23/96 Dll / GR SIZE SPF INTERVAL (TVD) KUD. 'B' Sand 9610' - 9632' (6897'-6918') Ku . 'A' San 9636' - 9666' (6921 '-6949') 9666' - 9692' (6949'-6973') 2 1/2" 4 2 1 12" 4 3 3/8" 6 2.1/2" guns loaded wI 10.5 gm Jumbo Jet charges (EHO = 0.52", TTP = 6.8") wI 90 deg. phasing. 3 3/8" gun loaded wI 22 gm. Jumbo Jet charges (EHO = 0.76". TTP = 6.4") wI 60 deg. phasing DATE REV. BY COMMENTS 12/31/95 08/22/98 10/31/98 MPU C-22A ori/r Elev. = 46.0' (N 22E) Orig. GL Elev. = 17.4' RT To TI 7" hng. = 30.12' (N 22E) 27/8" Cameo KBMM I 116' GLM (wI 1" sidepocket) "- Baker ZPX liner top paCker 8266' Baker 4.5" HMC Liner I 8281' Hng and Baker ZPX pkr. 4.5" 12.6 ppf, L-80, NSCT liner. ( J.e = 3.958", Cap. = 0.0152 bpf ~ Top of window at 8435' ..{!1d . , ,..........-- Original hole Fill tagged at 9885' wlm on ~12/26/95 4.5" landing collar (PBTO) I 4.5" float I shoe 9904' 9995' JBF Wellbore Sidetracked by Nabors 4ES MOO ESP RWO by Nabors 5S M. Linder RWO by Nabors 4-ES MILNE POINT UNIT WELL C-22A API NO: 50-029-22489-01 Tree: 3 1/8" - 5M WKM( Wellhead: 13 5/8" 5M F~. . Tbg. Hng: 13" x 3.5" FMC 20" 94 ppf, H-40, Btrc. I 112' KOP @ 500' Max. hole angle = 53 to 55 deg. fl 2650' to 7300' Hole angle across perforations = 22.5 deg. 9 5/8", 40 ppf, L-80 Btr9- 6715' I 2-7/8" 6.5 ppf, L-80 8rd EUE tbg. (Orift=2.347", Cap.=.0058 bpf 7" 26 ppf, L-80 Btrc. production casing ( 10 = 6.276", cap. = 0.0383 bpf) Stimulation Summary 12/28/95 - 91.25M Ibs of 20-40 carbolite behind pipe, Kup 'A' Sand, job went to flush. Perforation Summary Ref loa: 12/23/96 Dill GR SIZE SPF INTERVAL (TVD) KUD. 'B' Sand 2 1/2" 4 9610' - 9632' (6897'-6918') Ku . 'A' San 2 1/2" 4 9636' - 9666' (6921'-6949') 3 3/8" 6 9666' - 9692' (6949'-6973') 2.1/2" guns loaded wI 10.5 gm Jumbo Jet charges (EHO = 0.52", TTP = 6.8") wI 90 deg. phasing. 3 3/8" gun loaded wI 22 gm. Jumbo Jet charges (EHO = 0.76". TTP = 6.4") wI 60 deg. phasing DATE REV. BY COMMENTS MPU C-22A oril Elev. = 46.0' (N 22E) Orig. GL Elev. = 17.4' RT To TI 7" hng. = 30.12' (N 22E) Cameo glm. kbmm. wI bk latch # md tvd dg 5 4 3 2 1* 2216 3514 4470 5148 5648 2493 4693 6293 7453 8216 *at 8216'md or 1 joint above X nipple HES 2-7/8" X-Nipple I -8240 I I -8250 I I -8265 I I -8280 I 8266' 8281' I 7x 3.5" Baker $-3 Pkr. HES 2-7/8" XN-Nipple ( 2.250"id ) "- WLEG Baker ZPX liner top packer Baker 4.5" HMC Liner I Hng and Baker ZPX pkr. 4.5" 12.6 ppf, L-80, NSCT liner. (J.e = 3.958", Cap. = 0.0152 bpf ~ Top of window at 8435' ..{!1d . , ,..........-- Original hole Fill tagged at 9885' wlm on ~12/26/95 4.5" landing collar (PBTO) I 4.5" float shoe 9904' 9995' 12/31195 08/22/98 10/31/98 JBF Wellbore Sidetracked by Nabors 4ES MOO ESP RWO by Nabors 5S M. Linder RWO by Nabors 4-ES MILNE POINT UNIT WELL C-22A API NO: 50-029-22489-01 BP EXPLORATION AK MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: · THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor~ DATE: May 19, 2001 FROM' John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Milne point Unit C Pad May 19,2001' I traveled to BP's Milne Point Field to witness Safety Valve System tests. Lee Hulme was BP Rep. in charge of SVS tests. Testing was conduCted in a safe & efficient manner. This Pad is on 3 month test cycle due to failure rate above 9.9%. I reviewed the 8112198 supplement to the 3/30/94 SVS policy to discuss BP's options for keeping the wells with leaking Surface Safety Valves producing & injecting. Lee Hulme stated that servicing & repair of the valves could not be accomplished immediately. After review of the AOGCC Policy Supplement, i told Lee that the wells could stay on line if someone trained in Drill Site Operations manned the pad. ! requested the Pad be manned immediately & until the valves were repaired & re-tested. The AOGCC test report is attached for reference. Wells #7,8 & 25 were serviced & re-tested OK 5-20-01. Wells.#4,6 & 14 were shut in for repairs. .S, UMMARY: I witnessed SVS testing in Milne Point Field. 12 wells, 24 components tested. 6 failures witnessed. 25% failure rate. 20 well houses inspected. Attachments: SVS KRU 3K 5-18-01jc cc; NON-CONFIDENTIAL SVS MPU C Pad 5-19-01jc Alas~a Oil and Gas Conservation Commiss._a Safety Valve System Test Report Operator: BPX Operator Rep: Lee Hulme AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unk/Pad: Milne Point Unit C Pad Separator psi: LPS 140 HPS 5/19/01 . Well Permit Separ Set L/P Test Test Test Date o~ WAG, GIN J, Number Number PSI PSI Trip ,Code Code Code Passed GAS or CYCLE ¢-0i i8~450 140 "100 110 p p oiL c-02 1821940 ~ , , C-03 1820500 140 100 95 P P OIL , ,, C-04 1821260 140 100 110 P 4 OIL C-05A 1842430 140 100 100 P P OIL C-06 184241'0 4300 2000. 1950 P 4 WAG C-07 1850020 1401 100 95 P 4 OIL C-08 ' 1850140 '4300'! 2000 1900 P 4 WAG C.09 1850360 '140 100 105 P P ' oil C-13 1850670 ,, , C-14 1850880 140 100 100 P 4 OIL C-15 1851030 , , , C-17 1852630 , ,, C-20 1890150 C-21 1940800 C-22A ' 1951980 140 100 95 p P ..... 0IL , , C-23 1960160 , C-25A 1960210 4300 2000 1900 P 4 WAG C-26 1952060 C-28 19605901 ' C-36 1980010 C-3~"' 1972480` ' ~240 2002130 " C-10 " 18501501 4300 2000 1850 P P wAG Wells: 12 Components: 24 Failures: 6 Failure Rate: 25.00oA[~90 Day Remarks: RJF 1/16/01 Page 1 of 1 SVS MPU C Pad 5-19-01jc MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julia Heusser, Commissioner DATE: November 18, 2000 THRU: Blair Wondzell, ~ P. I. Supervisor ~r?,o[c~:) FROM: Lou Grim , ~ ~. SUBJECT: Petroleum Inspector SVS tests BPX C-pad Milne Point Unit Kuparuk River Field Saturday, November 18, 2000; I witnessed the SVS tests on BP× C pad in the Milne Point of the Kuparuk River Field. This was the three-month test for this pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although the fail rate of 13.6% was still above the 10% expectable limit. Again, the gas .injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARY: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, '1"1 wells, 22 components, 3 failures. Wellhouse Inspections; 14 wellhouses, 1 failure (leaking T.S.A.) Attachments: SVS MPU C pad 11-18-00 LG.XLS cc: Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad 11-18-00 LG.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi SUbmitted By: Lou Grimaldi Field/Unit/Pad: K.R.F./M.P.U./C pad Separator psi' LPS 140 Date: 11/18/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed gas or CYCLE C-01 1811430 140 100 120 e e OIL ~-02 1821940 C-03 1820500 140 100 105 P P OIL C-04 1821260 140 100 105 P 4 OIL C-05A 1842430 140 100 105 P P C-06 1842410 ,, C-07 1850020 140 100 110 P P OIL C-08 1850140 C-09 1850360 140 100 80 i p P OIL ,,, C-13 1850670 C-14 1850880 140 100 105 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 ~40 100 110 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P P WAG C-36 1980010 C-39 1972480 ~-19i 1852960! 4000 2000 2000 P 4 WAG Wells: 11 comPonents: 22 Failures: 3 Failure Rate: 13.6%[] 9o Day Remarks: C-03 has gas leak on Tubing Spool adapter, Develop.plan for repair and report back. 11/20/00 Page 1 of l V0kltrl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan SeamoUnt, Commissioner THRU: DATE: July 12, 2000 Blair Wondzell, P. I. Supervisor _ Petroleum IhsP(~c~r Safety Valve Tests Milne Point Unit B & C Pads July 9, 2000' I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, 9 wells, 18 components tested, '1 failure. 5.5% failure rate. MPU C Pad; 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments: SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON,CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorCVCLE C-01 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260: 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL ,C-08 1850140 iC-09 1850360 140 100 120 P 4 OIL C-13 1850670 C- 14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 ~~;i 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C-26 1952060 C-28 1960290 4000 2000 2000 P 43 WAG C-36 1980010 C-39 19724801 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: Remarks: 12 Components: 23 Failures: 6 Failure Rate: 26.0%[~ 90 r)av Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked, The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 V 1 v7irqm.xls STATE OF ALASKA ALASKA O,,_ AND GAS CONSERVATION COMrv,,SSION I--I Operation Shutdown I--]Stimulate [] Plugging [] Perforate [~Pull Tubing I~Alter Casing ~] Repair Well [~ Other Change Out ESP Operations performed: 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 2. Name of Operator 15. Type of well: 6. Datum Elevation (DI~'~¢~i~) BP Exploration (Alaska) Inc. [] Development KBE = 25.75 I [] Exploratory 7. Unit or Property Na~,e'~-*. 4. Location of well at surface 582' NSL, 2054' WEL, SEC. 10, T13N, R10E At top of productive interval 841' NSL, 4042' WEL, SEC. 14, T13N, R10E At effective depth 743' NSL, 3987' WEL, SEC. 14, T13N, R10E At total depth 715' NSL, 3967' WEL, SEC. 14, T13N, R10E [] Stratigraphic Milne Point Unit [] Service . ;.-- ,,.,..,; ~._://,',~ (~;.¢,, ,; 8. Well Number '-:. '-~.~ t,¢i~-: :.-, ..... 9. Permit Number / Approval'No. 95-198 10. APl Number 50-029-22489-01 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 9995 feet true vertical 7254 feet Effective depth: measured 9905' feet true vertical 7171 feet Casing Size Structural Conductor 80' 20" Surface 6685' 9-5/8" Intermediate Production 8408' 7" Liner 1729' 4-1/2" Plugs (measured) Junk (measured) Length Cemented 250 sx Arcticset I (Approx.) 1300 sx PF 'E', 250 sx Class 'G' 150 sx Class 'G' 200 sx Class 'G' MD TVD 112' 112' 6715' 4756' 8435' 5847' 8266'-9995' 5722'-7254' Perforation depth: measured true vertical 9610'-9632', 9636'-9666', 9666'-9692' 6897'-6918', 6921'-6949', 6949'-6973' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE tubing to 8156' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: [] Oil I~ Gas [] Suspended Service 17. I hereby certify that the foregoina is true and correct to the best of my knowledge Signed e'~~-- ~ Terrie Hubbl ....... Title Technical Assistant III Prepared By Name/Number: Date Terrie Hubble, 564-4628 Submit In Duplica'te-qf._~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt C Pad Well MPC-22A Page 1 Rig ~ [~a..~t'$ t/~ Date 10 February 99 Date/Time 15 Aug 98 15:00-22:00 22:00-22:30 22:30-01:00 16 Aug 98 01:00-06:00 06:00-08:00 08:00-00:30 17 Aug 98 00:30-04:30 04:30-06:00 06:00-06:15 06:15-08:30 08:30-09:30 09:30-15:00 15:00-16:00 16:00-18:00 18:00-18:15 18:15-18:30 18:30-19:00 19:00-03:30 18 Aug 98 03:30-04:30 04:30-05:30 05:30-05:45 05:45-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-11:00 11:00-11:30 11:30-16:00 16:00-18:00 18:00-18:15 18:15-23:00 23:00-23:30 23:30-02:00 19 Aug 98 02:00-02:15 02:15-02:30 02:30-04:00 04:00-05:00 05:00-05:30 05:30-06:00 Duration 7hr 1/2 hr 2-1/2 hr 5hr 2hr 16-1/2 hr 4hr 1-1/2 hr 1/4 hr 2-1/4 hr lhr 5-1/2 hr lhr 2hr 1/4 hr 1/4 hr 1/2 hr 8-1/2 hr lhr lhr 1/4 hr 1/4 hr lhr 1-1/2 hr 1-1/2 hr lhr 1/2 hr 4-1/2 hr 2hr 1/4 hr 4-3/4 hr 1/2 hr 2-1/2 hr 1/4hr 1/4hr 1-1/2 hr lhr 1/2 hr 1/2 hr Activity Rig moved 100.00 % Held safety meeting Fill pits with Brine Circulated closed in well at 8075.0 ft Removed Xmas tree Rigged up BOP stack Tested BOP stack Serviced Well control Held safety meeting Serviced Annular preventor Tested Annular preventor Retrieved Hanger plug Retrieved Tubing hanger Circulated at 8141.0 ft Held safety meeting Flow check Retrieved Tubing hanger Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run (cont... Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Installed Electrical submersible pumps Ran Tubing in stands to 1332.0 ft Held safety meeting Ran Tubing in stands to 8156.0 ft Installed Tubing hanger Installed Electric cable Ran Tubing on landing string to 8156.0 ft Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Installed Hanger plug Progress Report Facility M Pt C Pad Well MPC-22A Page l Rig (~~~ ~ Date 10 February 99 Date/Time 27 Oct 98 14:00-16:00 16:00-18:00 18:00-18:15 18:15-19:00 19:00-20:30 20:30-22:00 22:00-23:00 23:00-01:00 28 Oct 98 01:00-01:30 01:30-02:00 02:00-03:00 03:00-03:15 03:15-03:45 03:45-04:15 04:15-04:30 04:30-06:00 06:00-06:30 06:30-07:00 07:00-08:30 08:30-09:00 09:00-09:30 09:30-11:00 11:00-13:30 13:30-14:30 14:30-14:45 14:45-15:00 15:00-17:00 17:00-17:30 17:30-18:00 18:00-18:15 18:15-19:00 19:00-20:00 20:00-20:15 20:15-20:30 20:30-21:00 21:00-03:00 29 Oct 98 03:00-06:00 06:00-07:00 07:00-08:00 08:00-11:30 11:30-13:00 13:00-13:30 13:30-14:00 14:00-17:00 17:00-21:00 21:00-21:15 21:15-00:30 30 Oct 98 00:30-02:00 02:00-03:00 03:00-03:30 03:30-05:00 05:00-05:30 05:30-05:45 05:45-06:00 Duration 2hr 2hr 1/4 hr 3/4 hr 1-1/2 hr 1-1/2 hr lhr 2hr 1/2 hr 1/2 hr lhr 1/4 hr 1/2 hr 1/2 hr 1/4 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2hr 1/2 hr 1-1/2 hr 2-1/2 hr lhr 1/4 hr 1/4hr 2hr 1/2 hr 1/2 hr 1/4 hr 3/4 hr lhr 1/4 hr 1/4 hr 1/2hr 6hr 3hr lhr lhr 3-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 3hr 4hr 1/4 hr 3-1/4 hr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 1/2 hr 1/4 hr 1/4hr Activity Rigged down Drillfloor / Derrick Rig moved 90.00 % Held safety meeting Rig moved 100.00 % Rigged up Drillfloor / Derrick Rigged up Fluid system Fill pits with Brine Installed High pressure lines Retrieved Hanger plug Tested High pressure lines Functioned Production flowline valve - hydraulic Held safety meeting Bleed down well Circulated closed in well at 8028.0 ft Bullhead well Circulated closed in well at 8028.0 ft Circulated closed in well at 8028.0 ft (cont...) Monitor wellbore pressures Circulated at 8024.0 ft Monitor wellbore pressures Installed Hanger plug Removed Xmas tree Installed BOP stack Tested BOP stack Retrieved Hanger plug Installed Hanger plug Tested All functions Retrieved Hanger plug Installed Tubing retrieval string Held safety meeting Retrieved Tubing hanger Circulated at 8004.0 ft Tested Electric cable Rigged down Tubing hanger Rigged up Completion string handling equipment Pulled Tubing in stands to 51.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Rigged down sub-surface equipment - Electrical submersible pumps (cor Rigged up Slickline unit Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Rigged down Slickline unit Rigged up Completion string handling equipment Serviced Electrical submersible pumps Ran Tubing in stands to 2237.0 ft Held safety meeting Ran Tubing in stands to 7874.0 ft Serviced Electric cable Ran Tubing in stands to 8135.0 ft Rigged up Tubing hanger Serviced Electric cable Ran Tubing on landing string to 8155.0 ft Installed Hanger plug Removed BOP stack Progress Report Facility M Pt C Pad Well MPC-22A Rig (null) Page 2 Date 10 February 99 Date/Time 06:00-07:30 07:30-08:30 08:30-09:30 09:30-10:00 10:00-10:30 10:30-11:00 11:00-11:30 11:30-12:00 Duration 1-1/2 hr lhr lhr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr Activity Removed BOP stack (cont...) Installed Xmas tree Tested Xmas tree Retrieved Hanger plug Installed Hanger plug Rigged up High pressure lines Freeze protect well - 13.000 bbl of Diesel Rigged down High pressure lines ,/"I f-/" -Q r~e we'i ~ r'e( .... s t '" desoI'"':i ¥ t"~ i'"~.::c(!: e :..' , C 0 H H [.51 N T S r'~_ ._ R e- c e '~ v e d ? y e .2 ..... " STATE OF ALASKA ~- ALASK~ OIL AND GAS CONSERVATION C~JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-198 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22489-01 4. Location ofwell atsurface ~"i'.'~:,:'-': ~-::-:~-~ ,,.¢,~_%.~;~.~;%:~ 9. Unit or Lease Name 582' NSL, 2054' WEL, SEC. 10, T13N, R10E_ .,~-___ ~/ .... ~:-';'~..,' i ~;¢_,~.~.~ Milne Point Unit At top of productive interval~//-~ , ~~.~ ~ ;; ~:-~ ~ 10. Well Number 841'NSL, 4042'WEL, SEC. 14, TlSN, R10E ~ ~i:~l,~)~i I~~!~ MPC-22A At total depth ~ ._~./¢~_~__~i_ _ ~: ! ~. 11. Field and Pool 715' NSL, 3967' WEL, SEC. 14, T13N, R10E Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 25.75I ADL 047437 12. Date Spudded 113. DateT. D. Reached 114. Date Comp., Susp., or Aband. J15. Water depth, ifoffshore lO. Nc. of Completions 12/14/95 12/22/95 12/31/95 N/A MSL One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV setJ21. Thickness of Permafrosl 9995 7254 FTI 9905' 7171 F'r1 []Yes I~No I N/A MD| 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, DIL, CCL, JB 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# N80LHE 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 47# L-80 30' 6715' 12-1/4" 1300 sx PF 'E', 250 sx Class 'G' 7" 26# L-80 27' 8435' 8-1/2" 150 sx Class 'G' 4-1/2" 12.6# L-80 8266' 9995' 6" 200 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom !25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 2-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 8142' MD TVD MD TVD 9666'- 9692' 6949' - 6973' 9610'- 9632' 6897' - 6918' 9636' - 9666' 6921' - 6949' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9666' - 9692' Frac'd w/95,000# 20/40 Carbolite Behind Pipe Freeze Protect with 80 Bbls Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) February 4, 1996 I Electric Submersible Pump Date of Test Hours Tested :,PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE I GAS-OIL RATIO iTEST PERIOD I Flow Tubing Casing Pressure CALCULATED ~ OIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 0 Alaska 011 & Ga~ Con~. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mark__., 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk D 9423' 6726' Top Kuparuk C 9600' 6888' Top Kuparuk B 9610' 6897' Top Kuparuk A3 9640' 6925' Top Kuparuk A2 9650' 6934' Top Kuparuk A1 9663' 6946' Top Miluveach 9718' 6997' 31. List of Attachments Summary of Daily Drilling Reports, Surveys nd c0rr/~ct to the best of my knowledge 32' I hereby certify that the f°reg°ing is two ~Signed ' ~""~ ~~~L'J 'Rm Schofield . Title Senior Drilling Engineer Date / Prepared By Name/Number: Terrie Hubble, 564;4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 AAI SHARED SERVICE DAILY OPERATION~ PAGE: 1 WELL: MPC-22A BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 12/09/95 03:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 4ES WO/C RIG: 12/10/95 ( 1) TD: 0'( 0) 12/11/95 (2) TD: 0'( 0) 12/12/95 (3) TD: 8435' (8435) 12/13/95 ( 4) TD: 8482' ( 47) 12/14/95 ( 5) TD: 8482' ( 0) 12/15/95 (6) TD: 8439' ( 0) TEST BOP'S MW: 0.0 VIS: 0 MIRU. MOVE FROM MPJ-08 TO MPC-22A. RIG ACCEPTED @ 1500 HRS., 12/09/95. TEST CASING, SET TWC & TEST. ND TREE & NU BOP'S. TEST BOP'S. TEST WAIVED BY LOU GRIMALDI WITH AOGCC. PU 3-1/2" DP MW: 0.0 VIS: 0 CONT TEST BOP EQUIP. PULL TWC & MU LANDING JT. BOLDS & PULL HANGER TO FLOOR & LD. RIH WITH TUBING & TAG CEMENT RETAINER @ 8592'. DISPLACE WELL WITH BIOZAN MILLING FLUID. SPOT PILL IN SUMP HOLE. POOH WITH TUBING. DRIFT & STRAP SAME. CHANGE RAMS IN BOPS & TEST. PU SECTION MILL & BHA & RIH WITH SAME ON 3-1/2" DP. MILLING SECTION MW: 0.0 VIS: 0 CONT TO PU 3-1/2" DP SLM & DRIFT. CUT DRLG LINE. CONT TO PU 3-1/2" DP T/8587' LD DP. START CASING. CUT 8435'. REPAIR SHOE IN DRILL COLLAR TO MUD PUMP. MILL SECTION F/8435' T/8446' RIH WITH 3-1/2" DP MW: 0.0 VIS: 0 MILL SECTION F/8446' T/8482'. BLOW DOWN KELLY & PULL UP IN CASING. REPAIR LINER LEAK ON MUD PUMP. RUN SWEEPS & CIRC & RECIPROCATE TO CLEAN HOLE. POOH & LD JARS & DRILL COLLAR & SECTION MILL. RIH OPEN ENDED TO SET SIDETRACK PLUG. TIH WITH BHA %2 MW: 0.0 VIS: 0 CONT RIH WITH 3-1/2" DP, OPEN ENDED T/8508'. CIRC & BATCH MIX CEMENT. TEST LINES & SET PLUG WITH BJ. PUMP CEMENT. CIP @ 1030 HRS, 12/13/95. POOH, SLOW T/7022'. HES SSQZ CEMENT & HOLD BLEED DOWN. POOH. CLEAN BOP'S. PULL WR & SET TEST PLUG. TEST BOP'S. PU BHA %2 & ORIENT TOOLS & RIH FILLING EVERY ROW. RIH WITH BHA %2 MW: 0.0 VIS: 0 RIH WITH DP. FILL EACH ROW. TAG CEMENT @ 8216'. CBU. DRILL CEMENT F/8216' T/8234'. CBU. CHANGE 6" PUMP LINERS TO 5" DUE TO EXCESSIVE PRESSURE. CHANGE SHAKER SCREENS. DRILL OUT CEMENT F/8234' T/8436'. ORIENT TOOL FACE & SLIDE F/8436' T/8439'. TEST SURFACE LINES FOR LEAKS. POOH & LD MOTOR. PU MOTOR & ORIENT. RIH WITH BHA %2 & FILL DP & TEST MOTOR EVERY 1000' RECEIVED SEP 5 0 1996 Aiask~ Oil & Gas Cons. commission Anchorage : MPC-22A ~PERATION: RIG : NABORS 4ES PAGE: 2 12/16/95 ( 7) TD: 8590' ( 151) POOH WITH BHA #2 MW: 0.0 VIS: 0 RIH WITH BHA ~2, FILL DP EVERY 1000'. ORIENT TOOL & SLIDE F/8439' T/8590'. CBU & PUMP PILL. POOH. SLIP DRILLING LINE. POOH. 12/17/95 (8) TD: 9080' ( 490) SHORT TRIP T/8435' MW: 0.0 VIS: 0 POOH WITH BIT #1 RR. RU BIT #2, ORIENT & RIH. TEST MWD. RIH, FILL DP. WASH F/8588' T/8590'. DRILLED F/8590' T/8704' CIRC. WO GUZZLER. DRILLED F/8704' T/9080'. CBU WITH LVP. PILL & SHORT TRIP TO WINDOW @ 8435'. 12/18/95 (9) TD: 9305'( 225) 12/19/95 (10) TD: 9321' ( 16) CLEAN SUCTION SCREENS MW: 0.0 VIS: 0 SHORT TRIP TO TOP OF WINDOW. DRILLED F/9080' T/9300' CIRC, PUMP LOW VIS PILL, PUMP PILL. POOH & LD 2 MONELS. MU BIT #3, ORIENT MOTOR WITH MWD. RIH, FILL PIPE EVERY 15 STDS. NO FILL. DRILLED F/9300' T/9305'. CLEAN SUCTION SCREENS. W O W MW: 0.0 VIS: 0 DRILLING F/9305' T/9321'. POOH T/8435'. WAIT ON WEATHER. 12/20/95 (11) TD: 9332' ( 11) DRILLING MW: 0.0 VIS: 0 WAIT ON PHASE III WEATHER. TEST CHOKE MANIFOLD T/5000 PSI. RIH W/DP T/9200'. WASH & REAM F/9200' T/9321'. DRILLED F/9321' T/9332' 12/21/95 (12) TD: 9412' ( 80) RIH W/ BHA #5 MW: 0.0 VIS: 0 DRILLING F/9332' T/9412'. CBU & PUMP DRY JOB. POOH. CHANGE BIT, SLV ON MOTOR & CHECK TOOL FACE ORIENTATION. RU & TEST BOPE T/5000 PSI. RD TEST TOOLS. MU BHA #5, SERVICE MWD & RIH. 12/22/95 (13) TD: 9866'( 454) 12/23/95 (14) TD: 9995' ( 129) DRILLING MW: 0.0 VIS: 0 RIH T/4500'. SLIP & CUT DRILL LINE. RIH, FILL EVERY 15 STDS. WASH TO BOTTOM F/9357'. DRILLING F/9412' T/9866' CIRC & RAISE MW MW: 0.0 VIS: 0 DRILLING F/9866' T/9995'. CBU & PUMP PILL. POOH T/8435' MONITOR WELL & RIH T/9995' TD. CIRC LO VIS SWEEP. CBU & COND MUD. PUMP PILL BD & SB KELLY. POOH 3 STDS. MONITOR WELL & RUN TO BOTTOM @ 9995'. MONITOR WELL & PULL 13 STDS, & RUN T/9995' CBU GAS & OIL CUT OIL. RAISE MUD WT. MONITOR WELL. POOH, C~ECK FOR FLOW @ 8435' NO FLOW. CONT POOH 10 STDS, OBSERVE LIGHT FLOW. MONITOR WELL. RIH T/9995'. CIRC & RAISE MUD WT. : MPC-22A oPERATION: RIG : NABORS 4ES PAGE: 3 12/24/95 (15) TD: 9995' ( 0) 12/25/95 (16) TD: 9995' ( 0) 12/26/95 (17) TD: 9995' ( 0) 12/27/95 (18) TD: 9995' ( 0) RIH W/4.5" LINER MW: 0.0 VIS: 0 CIRC & COND HOLE. MONITOR WELL. MIX & PUMP PILL. MONITOR WELL. POOH WITH 3-1/2" DP & LD BHA. ND FLOW NIPPLE & NU PERFORATION FLANGE. RU ATLAS & RUN #1 WITH GR/DIL F/9500' T/9995'. POOH & RD ATLAS. RIH 7 STDS HWDP & POOH LAYING DOWN SAME. RIH & RUN 4-1/2" LINER & MU BAKER LINER HANGER. CIRC LINER VOLUME. RIH WITH 4-1/2" LINER ON 3-1/2" DP. FILL EACH ROW & DRIFT. BREAK CIRC @ 9812' MW: 0.0 VIS: 0 RIH WITH 4-1/2" LINER ON 3-1/2" DP TO 7" CASING SHOE @ 8435'. FILL DP EVERY 5 STDS. BREAK CIRC. CONT RIH WITH 4-1/2" LINER T/9960' FILL DP & WASH DOWN 4-1/2" LINER F/9960' T/9995'. PUMP WATER, TEST CMT LINES, PUMP WATER, SWEEP, 41 BBLS 'G' CEMENT. DROP PLUG. DISPLACED CEMENT WITH RIG PUMP. BUMP PLUG. SET LINER HANGER, CONT PRESSURE. SET TOP PACKER. BLED PRESSURE OFF. FLOAT HELD. RELEASE RUNNING TOOL & PU 5'. REV CIRC EXCESS CEMENT & COND MUD. LD CMT HEAD & 10 STDS 3-1/2" DP. CONT POOH TO BAKER RUNNING TOOL & LD SAME. RU FLOOR, MU MILL, PU DC'S & 45 JTS 2-7/8" PAC DP. CONT RIH WITH 3-1/2" DP & TAG CMT @ 9812'. LD 4 JTS. PU KELLY & BREAK CIRC. ATTEMPT TO FREE PERF GUN MW: 0.0 VIS: 0 DRILLING CEMENT F/9812' T/9905'. CIRC & COND HOLE, CLEAN PITS, TAKE ON BRINE, MIX SWEEP. TEST LINER, LAP & 7" CASING. OK. DISPLACED & CLEAN WELL WITH SEAWATER & XANVIS PILL & CHANGE OVERF TO BRINE. REV CIRC. TEST LINER, LAP & 7" CASING WITH BRINE. POOH & LD 15 JTS 3-1/2" DP. SLIP 42' DRILLING LINE. CONT POOH LD 3-1/8 TRISTATE MILL. MD FLOWLINE & RISER. NU SHOOTING FLANGE. RU ATLAS & TEST LUBRICATOR. RUN ~1, RIH WITH CARRIER GUN. MAKE GR/CCL CORRELATION PASS. PULL UP. RUN #2 WITH SAME GUN & NEW GR/CCL. PULL INTO SHOOTING POSITION, FIR GUN. PERF LINER F/9666' T/9692'. ATTEMPT TO LOG OFF. PULLING WT. NO TOOL MOVEMENT. WORK LINE. PUMP BRINE TO PRESSURE 7" CASING & 4-1/2" LINER. PERFS DO NOT APPEAR TO BE TAKING FLUID. RU ATLAS MW: 0.0 VIS: 0 GUN STUCK, NO TOOL MOVEMENT. WORK LINE T/7000 LBS. RU & DROP KINLEY LINE CUTTER, CUT LINE & POOH WITH E LINE & CUTTER. RECOVER 9664' OF LINE. RD ATLAS. ND SHOOTING FLANGE & NU FLOW LINE. MU FISHING ASSY #1 & RIH T/9660'. ENGAGE FISH & PUSH T/BOTTOM @ 9905'. DROP BAR, CIRC & SHEAR W/1500 PSI. POOH, LD FISH & ASSY. ND FLOW LINE & PITCHER NIPPLE. NU SHOOTING FLANGE. RU ATLAS. : MPC-22A ~PERATION: RIG : NABORS 4ES PAGE: 4 12/28/95 (19) TD: 9995' ( 0) 12/29/95 (20) TD: 9995' ( 0) 12/30/95 (21) TD: 9995' ( 0) 12/31/95 (22) TD: 9995' ( 0) 01/01/96 (23) TD: 9995' ( 0) RIG BJ TO FRAC MW: 0.0 VIS: 0 RIH WITH GR/JB TO 9880'. RIH %2 GUN 9636'-9692'. RIH #3 GUN 9610'-9632' RIH ~1 GR/JB TO 9885'. POOH & LD SAME. ND PERF FLANGE & NU FLOWLINE & PULL WR & INSTALL TEST PLUG & CHANGE RAMS TO 4-1/2". TEST BOP'S & PULL TEST PLUG & INSTALL WEAR BUSHING. RU TO RUN FRAC ASSY. PU BAKER PACKER & PREDAT GAUGES & RIH ON 4-1/2" TUBING. RIGBJ & TEST LINES & PICKLE TUBING. SET PACKER & TEST & RIG BJ. LAYING DOWN FRAC PAC MW: 0.0 VIS: 0 RIG BJ & TEST SURFACE LINES. SET 35K ON PACKER & PERFORM INJECTIVITY TEST & DATA FRAC & ANNALYIZE RESULTS & DESIGN FRAC. USED CARB BEHIND PIPE, FLUSH WITH BRINE. RD BJ & RU TO MONITOR PSI ON TUBING. ALLOW SAND CARRIER TO BREAK. RELEASE PACKER & MONITOR WELL. CBU & MONITOR. POOH, LAYING DOWN 4-1/2" TUBING. LD 3-1/2" DP MW: 0.0 VIS: 0 RU FLOOR TO RUN 3-1/2" DP. CHANGE RAMS & TEST. MU 2-7/8" MULE SHOE & RIH ON 2-7/8" PAC & 3-1/2" DP T/8738' TAG SD. REVERSE OUT SAND F/8738' T/9904'. CIRC & COND HOLE WITH ZANVIS SWEEP & CHANGE OUT BRINE IN HOLE WITH NEW FILTERED BRINE. LAYING DOWN 3-1/2" DP. RIH W/ ESP COMPLETION MW: 0.0 VIS: 0 LD DP TO TOP OF LINER. REVERSE CIRC & REC AT TOP OF LINER. CONT LAYING DOWN DP. CUT DRLG LINE. CONT LAYING DOWN DP. CHANGE RAMS IN BOP TO 2-7/8" & TEST. RU & RUN IN HOLE WITH ESP COMPLETION. RELEASED @ 2000 HRS,12/31 MW: 0.0 VIS: 0 CONT RIH WITH ESP COMPLETION. MU HANGER & SPLICE ESP CABLE. LAND HANGER & RILDS. SET TWC. ND BOP'S. NU TREE & TEST. FREEZE PROTECT WELL WITH 65 BBL DIESEL DOWN ANNULUS & 15 BBL DOWN TUBING. SET BPV. SECURE WELL & RIG DOWN CELLAR LINES ETC. RIG RELEASED @ 2000 HRS., 12/31/95. SIGNATURE: (drilling superintendent) DATE: SHARED SERVICES DRILLING MILNE PT/MPC-22A 500292248901 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/28/95 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 8402.05 5822.51 5796.76 8435.00 5847.39 5821.64 8440.00 5851.19 5825.44 8528.00 5921.08 5895.33 8579.00 5964.22 5938.47 8610.00 5991.14 5965.39 8642.00 6019.10 5993.35 8673.00 6046.32 6020.57 8705.00 6074.54 6048.79 8736.00 6101.91 6076.16 8766.00 6128.47 6102.72 8798.00 6156.90 6131.15 8829.00 6184.63 6158.88 8861.00 6213.47 6187.72 8892.00 6241.47 6215.72 8923.00 6269.37 6243.62 8955.00 6298.12 6272.37 8986.00 6326.18 6300.43 9018.00 6355.35 6329.60 9049.00 6383.80 6358.05 9081.00 6413.40 6387.65 9113.00 6443.18 6417.43 9144.00 6471.89 6446.14 9175.00 6500.28 6474.53 9207.00 6529.24 6503.49 9238.00 6557.14 6531.39 9333.00 6643.36 6617.61 9424.00 6726.54 6700.79 9520.00 6814.53 6788.78 9615.00 6901.91 6876.16 9710.00 6989.74 6963.99 9804.00 7077.04 7051.29 9898.00 7164.44 7138.69 9933.00 7196.99 7171.24 9995.00 7254.63 7228.88 ._ kY-SUN DRILLING SERVICES PAGE ANCHORAGE ALASKA ~~-- / /.?~. DATE OF SURVEY: 121495 MWD SURVEY JOB NUMBER: AK-MW-50122 KELLY BUSHING ELEV. = 25.75 FT. OPERATOR: BP EXPLORATION COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 41 15 S 42.65 E .00 4566.26S 3016.28E 5472.12 40 39 S 42.63 E 1.85 4582.15S 3030.91E 5493.40 40 32 S 42.62 E 2.02 4584.54S 3033.11E 5496.60 34 17 S 34.53 E 9.02 4626.08S 3066.59E 5549.65 30 12 S 28.80 E 10.02 4649.18S 3080.93E 5576.83 29 12 S 24.86 E 7.07 4662.87S 3087.86E 5592.10 29 0 S 20.40 E 6.81 4677.22S 3093.85E 5607.41 28 12 S 21.60 E 3.18 4691.08S 3099.16E 5621.94 28 6 S 21.70 E .35 4705.11S 3104.73E 5636.75 27 53 S 20.70 E 1.65 4718.68S 3109.99E 5651.01 27 30 S 18.90 E 3.09 4731.80S 3114.72E 5664.60 27 6 S 19.10 E 1.28 4745.67S 3119.50E 5678.86 26 0 S 22.40 E 5.93 4758.63S 3124.40E 5692.40 25 23 S 21.80 E 2.04 4771.48S 3129.62E 5706.04 25 23 S 22.00 E .29 4783.82S 3134.58E 5719.10 26 17 S 26.20 E 6.58 4796.15S 3140.10E 5732.45 25 47 S 25.60 E 1.77 4808.79S 3146.24E 5746.41 24 30 S 23.70 E 4.94 4820.76S 3151.74E 5759.45 24 0 S 21.40 E 3.34 4832.89S 3156.78E 5772.38 22 51 S 21.80 E 3.71 4844.35S 3161.32E 5784.48 21 43 S 22.70 E 3.72 4855.59S 3165.91E 5796.41 21 14 S 24.30 E 2.37 4866.33S 3170.58E 5807.97 23 0 S 25.00 E 5.77 4876.94S 3175.45E 5819.53 24 22 S 25.70 E 4.48 4888.20S 3180.79E 5831.88 25 56 S 29.10 E 6.67 4900.26S 3187.05E 5845.42 25 47 S 35.20 E 8.59 4911.70S 3194.24E 5858.93 24 0 S 47.50 E 5.76 4941.67S 3220.42E 5898.29 23 51 S 42.50 E 2.23 4967.74S 3246.50E 5934.33 23 17 S 40.60 E .98 4996.47S 3271.97E 5972.27 22 53 S 37.50 E 1.35 5025.40S 3295.45E 6009.30 21 53 S 36.00 E 1.21 5054.40S 3317.12E 6045.41 21 36 S 29.80 E 2.46 5083.59S 3336.02E 6080.19 21 36 S 25.50 E 1.68 5114.22S 3352.07E 6114.64 21 36 S 24.00 E 1.58 5125.92S 3357.46E 6127.39 21 36 S 24.00 E .00 5146.77S 3366.74E 6149.95 RECEIVED Alaska Oil & C~a~ Cons. Commi~ion Anchorage .{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE PT/MPC-22A 500292248901 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/28/95 DATE OF SURVEY: 121495 MWD SURVEY JOB NUMBER: AK-MW-50122 KELLY BUSHING ELEV. = 25.75 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6150.14 FEET AT SOUTH 33 DEG. 11 MIN. EAST AT MD = 9995 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 147.26 DEG. TIE IN POINT 8402.05 WINDOW POINT 8435 INTERPOLATED DEPTH 9995' S~ J~Y-SUN DRILLING SERVICES ANCHOR3~GE ALASKA PAGE 3 SHARED SERVICES DRILLING MILNE PT/MPC-22A 500292248901 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/28/95 DATE OF SURVEY: 121495 JOB NUMBER: AK-MW-50122 KELLY BUSHING ELEV. = 25.75 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTAi~GU~ COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 8402.05 5822.51 5796.76 9402.05 6706.47 6680.72 9995.00 7254.63 7228.88 4566.26 S 3016.28 E 2579.54 4961.19 S 3240.50 E 2695.58 116.04 5146.77 S 3366.74 E 2740.37 44.79 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE PT/MPC-22A 500292248901 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/28/95 DATE OF SURVEY: 121495 JOB NUMBER: AK-MW-50122 KELLY BUSHING ELEV. = 25.75 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8402.05 5822.51 5796.76 4566.26 S 3016.28 E 2579.54 8406.48 5825.75 5800.00 4568.48 S 3018.33 E 2580.73 1.19 8533.59 5925.75 5900.00 4628.65 S 3068.28 E 2607.84 27.11 8649.59 6025.75 6000.00 4680.65 S 3095.14 E 2623.84 16.00 8762.94 6125.75 6100.00 4730.46 S 3114.26 E 2637.19 13.35 8874.60 6225.75 6200.00 4776.90 S 3131.79 E 2648.85 11.66 8985.53 6325.75 6300.00 4820.58 S 3151.66 E 2659.78 10.93 9094.28 6425.75 6400.00 4860.09 S 3167.83 E 2668.53 8.75 9203.12 6525.75 6500.00 4898.77 S 3186.23 E 2677.37 8.84 9313.69 6625.75 6600.00 4936.16 S 3214.75 E 2687.94 10.58 9423.13 6725.75 6700.00 4967.48 S 3246.26 E 2697.38 9.44 9532.22 6825.75 6800.00 5000.14 S 3275.12 E 2706.47 9.09 9640.88 6925.75 6900.00 5033.39 S 3301.58 E 2715.13 8.66 9748.81 7025.75 7000.00 5066.14 S 3325.56 E 2723.06 7.93 9856.38 7125.75 7100.00 5100.43 S 3345.41 E 2730.63 7.57 9963.94 7225.75 7200.00 5136.33 S 3362.09 E 2738.19 7.55 9995.00 7254.63 7228.88 5146.77 S 3366.74 E 2740.37 2.18 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOR3kGE AK, 99501. Date: 4 January 1996 RE: Transmittal of Data ECC #: 6553.00 Sent by: HAND CARRY Data: LDWG Dear Sir/Madam, Reference: MPC- 22A MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run ~ 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services Received by: 5600 B Street Suite 201 Anchorage, AK 99518 .~~. ~) 563-7803 ~ '"%'~'~?" ~.~-~. Date .¥~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Reference: BP MPC-22A MILNE POINT / mmARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 PFC/PERF FINAL BL+RF Date: RE: 4 January 1996 Transmittal of Data ECC #: 6553.01 Sent by: HAND CARRY Data: PFC/PERF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 RECEIV u Anchorage, ~a,, Cons. Commission An~orage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 28 December 1995 Transmittal of Data ECC ~: 6553.00 Sent by: HAND CARRY Data: LDWG Dear Sir/Madam, Reference: MPC-22A MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 DIFL FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 . Or FAX to (907) 563-7803 Received~~~ ~/~~.~ Date: Oil ~ G~ Cons. '~"mmission A",~ora~e ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOI~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 8, 1995 Randy Thomas Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPC-22A BP Exploration (Alaska), Inc. Permit No. 95-198 .... Sur. Loc. 582'NSL, 2054'WEL, Sec. 10, T13N, R10E, UM Btmnhole Loc. 706'NSL, 4018'WEL, Sec. 14, T13N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 'nc C~ai~man~- ~ BY ORDER OF THE I$SION dlf/Enclosures cc'. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Typeofwork Drill Fq RedrillE'lllb. TypeofwelI. Exploratory[] Stratigraphic Test[~ DevelopmentOil[] Re-Entry [] DeepenI-iI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 48 f e et Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047437 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 582' NSL, 2054' WEL, SEC. 10, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 846' NSL, 4076' WEL, SEC. 14, T13N, RIOE MPC-22A 2S100302630-277 At total depth 9. Approximate spud date Amount 706' NSL, 4018' WEL, SEC. 14, T13N, RIOE 12/10/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 025516 1262 feet No Close Approach feet 2560 9995'MD/7223' TVD (SS) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 8450 feet Maximum hole angle,~0.3~ o Maximum sudace 3500 psig At total depth (TVD) 7223' /3980 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 6" 4-1/2" 12. 6# L-80 NSCT 1695' 8300' 5750' 9995' 7223' 155 sx Class 'G' .RFCFiVEB 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 10065 feet Plugs (measured) OEO - 7 true vertical 7284 feet AJaska & GasCons. Comm sion Effective depth: measured 9932 feet Junk (measured) ,Arlchorage true vertical 7162 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 20" 250 sxAS (approx.) 112' 112' S u rface 6685' 9'5/8" 1300 sx PF 'E', 250 sx 'G' 6715' 4758' Intermediate P rod uct ion 9226' 7" 150 sx Class 'G' 9253' 6540' Liner 1014' 5" 120 sx Class 'G' 9050'- 10064' 6354'-7284' Perforation depth' measured 9644'-9726', 9582'-9586', 9558'-9564', 9472'-9478'(squeezed off) true vertical 6898'-6973', 6841'-6845', 6819'-6825', 6741'-6746'(squeezed off) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~ _.__ Title ~ Date Commission Use Only Permit Number IAPI number IAppr/ov~l ,da,~ See cover letter ¢'Dz'"'" /~;~E [50-4:~2.--~'-- .2- ~/-'//~'~""'O /i lC~ c.., '" ¢,~-- for other requirements Conditions of approval Samples required [] Yes J~ No Mud log required []Yes ,j~ No Hydrogen sulfide measures [] Yes [] No Directional survey required [~ Yes [] No Required working pressure for BOPE V12M; FI3M; ,~5M; [-I10M; I-I15M; Other: Original Signed By by order of // Approved by David W. Johnston Commissioner tne commission Date¢/2~ Form 10-401 Rev. 12-1-85 Submit in )licate I WellName: IMP C-22A Redrill Plan Summary I Type of Redrill (producer or injector): ] Oil Producer Surface Location: 582' FSL, 2054' FEL, S10, T13N, R10E, UM Target Location: 846' FSL, 4076' FEL, S14, T13N, R10E, UM Bottom Hole Location: 706' FSL, 4018' FEL, S14, T13N, R10E, UM ]AFENumber: ] 339001 ] I Estimated Start Date: I Dec 10, 95 IMD: 19,995' I ITVD: Well Design (conventional, slimhole, etc.): I Rig: I Nabors 4ES ~' Operating days to complete: 118 7,223'ss I Irm Ely, ~8' I Twin Sidetrack (6" hole size) Objective: The objective is to side-track from the existing MPC-22 wellbore, which was plugged back earlier in 1995 due to a sanded up ESP and could not be retrieved. The primary target includes the Kuparuk A3 and A2 sands with additional potential in overlying B sands which is approximately 120 ft west of the original C-22 location. The well will be completed with 4-1/2" L-80 production liner, frac stimulation and 2-7/8" L-80 tubing with ESP. Mud Program: A maximum mud weight of 10.80 ppg LSND water based mud will be used for drilling the 6" side-track hole. ISpecial design considerations ]none Depth Density PV YP INT 10MIN FL OIL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 8.6 15 12 4 8 8 0 5 to to to to to to to to to Target 10.8 18 15 10 12 4 0 8 Milling fluid properties are: l Window 18.6-8.81200-3001 50-70130-501S0-60I 6-8 I 0 I 5 I RECEiVi:D OE¢ - 7 '199~ Alaska Oil & Gas Cons. Commission Anchorage MP C-22A Redrill Plan Summary Page 1 Directional: IKoP: 18,450' MD I I Maximum H°le Angle: 140'31 degrees @ wind°w I Close Approach Well: none (divert from the original C-22 wellbore) Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVDss MDfrVDss 6 4.5" liner 12.6# L-80 NSCT 1695' 8300'/5750' 9995'/7223' N/A 2-7/8" tbg 6.5# L-80 NSCT 8200' Surface 8250'/5700' Cement Calculations: I Liner Size: 1 4.5" production liner I IBasis:I 30% open hole excess, 80' shoe joint, 150' liner lap and 150' excess above liner with DP. Total Cement Volume: [ 1551 sxs of Class G Blend @ 1.15 ft3/sx ( Estimated Volume ) Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind-shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and mud fluid system schematics on file with AOGCC. Hazards and Contingency Plans 1. This is the first side-track work for Nabors 4ES in Milne Point, however, we will use all Prudhoe Bay recommended side-track practices to complete this project. 2. Nabors 4ES does not have de-sander and centrifuge as part of a complete solids control equipment, but we will use "dump and dilute" method to control the solid contents which will be sufficient to complete this 1500' of side-track interval. RECEiVeD o£¢ - 7 1995 Alaska Oil & Gas Cons. Commission MP C-22A Redrill Plan Summary Page 2 Rie-Work: -- Operations Summary'. o . o . o o . . o Run a 4-1/2" 6.5# L-80, NSCT liner with 7" packer / hanger to bottom in the 6" hole and space out for about 150' of lap. Refer to Standard Recommended practices for liner running procedure. Reciprocrate liner 20-30' during circulation and cementaiton. Cement the liner in place with the total cement volume based upon 30% open-hole enlargement plus the 80' shoe volume, 150' liner lap and 150' excess above liner with DP. Set liner hanger / packer and reverse out clean. POOH and LD liner running tools. PU 3-7/8" bit on 2-7/8" PAC stinger. RIH and clean out 4 1/2" liner to landing collar. Circulate hole clean. Pressure test the liner lap to 3500 psi for 30 min. Displace the hole with clean weighted brine and POOH. RU Atlas E-line unit and perforate Kuparuk A sand with 3-3/8" guns at 6 SPF, 22 gm RDX charges, 0.76" EHD, 6.4" TTP big hole charges. The detailed perforation interval will be provided after reviewing the MWD/GR logs. RD Atlas unit. RU BJ frac equipment and fracture stimulate Kuparuk A sands utilizing approximately 200M lbs of ISP. The well will be fracced down the casing and a data- frac will not be performed on this well. RD BJ frac equipment. RIH with 2-7/8" mule shoe and 2-7/8" PAC stinger on 3-1/2" DP. Clean out well to PBTD with kill weight brine. POOH and LD workstring. Run 2-7/8" L-80 6.5# EUE tubing per standard tubing running procedure. Position the Centrilift ESP motor at 50' MD above the liner top packer and a 2-7/8" X 1" GLM at 100' below the tubing hanger. RECOMMENDED ESP COMPLETION (RERUN ORIGINAL 2-7/8" 6.5# L-80 EUE TBG): ESP ASSEMBLY (PHD, MOTOR, FLAT CABLE, TANDEM SEAL SECTION, PUMP INTAKE, PUMP DISCHARGE HEAD) 8' 2-7/8" 6.5# EUE PUP 2-7/8" 6.5# EUE TUBING (+/-8100') 10' 2-7/8" PUP 2-7/8" X 1" GLM (w/dummy) 10' 2-7/8" PUP 3 JTS OF 2-7/8" 6.5# EUE TUBING 5' 2-7/8" PUP BELOW TUBING HANGER 2-7/8" FMC TUBING HANGER (W/ESP PORTS) Land tubing and run in lock down screws. Test tubing hanger to 5000 psi. Set TWC, ND BOPs and NU tree and test to 5000psi. Pull TWC with lubricator. Freeze protect well with diesel to 2000'TVD. Set BPV, close valves and secure the well for releasing the rig. 10. Complete appropriate documentation and hand-over to Production. MP C-22A Redrill Plan Summary Page 3 'J, 04.~5 1~:42_F~ ~o~e~. ~e~vlces ]~i[tlng · ~ S±~e PLane~ Zone4 .e Pt '. NPC S~u±~ K~C-22A HALLIBURTOM DRILLIMG iP_/4/g5 1 D22 ~m 40,31 ~ 8450 MD KKP / TIE IN / START 5810 5831 586O 5887 .5015 DATA E0,66 9t45 931t 8 g~31 H~ M<-lg 9398 HD TKUC 8~HD TKUB RECEiVeD DEC - 7 ]99~ Ai~a Oil & Gas Con~. Commi~ion 89595HD T~K~/ ~ 5~ 7'~,70 ~4.67 6121.85 SI4OD8 Surs~ey Rel'mmce= WELLHEAD Refe~n~Wm. ld Coordinate: LaL 70.2~.72, N- Long. 149.31.21W Ref~.~c~ GRID System: AIs.~c~ Stale Plane Zone: Al~ks 4 Rdctenoe GRID Coo~d~t~': (R): 6029865.97 N 55841 !.03 E No,it Aligned To: TRUE NORTH Ye.~dc~l Section ~e: ~ Halliburton Energy Services - Drilling Systems PSL Proposal Report Co~cuJaled u~ing lhe Mtnhnum Cur~alur~ Afelhod Computed u~ing WIN-CADD$ REVZ I.B Ve,'lJca! Sec6on Plane: 147.26 Wt-~J e~ Date: 12/4/95 Tin~ 11C~5 az Wellln~ ID: MPC-22AWp2 Lazl Revision: 12/4/95 BPX-5'h~ed Se..rvlces Drlll~g Al~ka Stale, Plane: Zone.4 Milne Pt: MPC Slot: MPC-2'2A Welll~t.b: MPC-22AWp2 Mg~u_red ~ Driit Subs~ T~q) Course T O T A L O~ C~lg~ ~ V~ BuUd W~ D~ ~ ~t~ ~ ~ ~ ~ H~ D~. V~ (~) (~.) (~C.) iff) (~) (~) ia) (a) (fl) (~) (tO (~.) (n) (d~ (d~O (~l~) (~ (~) (~ (~t) (~) (~.) (~ KOP / ~ IN IST~T OF C~VE ~ 4.~ ~1~ R 85~.~ 36.61 1~9.83 5~8.3~ 59~6.3~ I~.~ ~37.~S 3~.07E ~253,95 561528.~ 5557.~1~146.41. 55~.50 -3.70 2.~ 4.~ 1~.~ 4747.35~ ~9.~6E 246.~4 ~.89 49.~3 35.87 ~ 86~.~ 32.97 142,74 5980.~ ~1~,~ I~.~ ~81,~S 3115.79~ ~.79 561~.17 ~.91~1~.36 5623.21 -3.64 2.91 4,~ 14~5 47~75~ ~E ~9.~ 47.74 49.67 35.82 ~ ~.~ ~.41 146,~ ~5.~8 61~8 1~.~ 47~,~ S 3145.91~ ~167,96 561594.~ 5675,63~ 146,~4 5674.91 - -3.56 3.53 4.~ !~ 4835.49 ~ ~1~ 251.35 ~.55 49.93 35.73 ~ 8~.~ ~.~6 150,66 615~.5~ 61~.5~ I~.~ 4763.51 S 3170.28E ~1~,65 ~!619.33 5~.~146.~5 5721.~3 -3,44 4.39 4.~ 150.~ 4875,41 ~ ~.14~ 253.~ 49.~ ~.~ 35.~ ~ ~50.~ 2~69 15~.25 6~5.65 6~.65 !~.~ ~.26 S 3188.78 E ~2~2,06 561~8.1~ 576~88~ 146.~ 5762.~ -3.27 5.~ 4,~ 1~.5 4912.~ ~ ~5.16E 254.30 49.~ ~.~ 35.51 MWD END OF C~ 160,~ ~6.9~ 63~,92 65.9~ ~,~ S 31~.7~ E ~69.~ 561~7.26 5786,69~ 146.45 578~.12 -3,07 6.93 4,~ 157.~ 49~.08 g 3~3.8~ E 255.0~ 50,41 ~.15 35.45 ~ ~.55 20.66 160,R2 6373.~ ~11.~ 70.62 4~6.42~ 3205.92E ~24~6,~ 561~5.~ 5810.8~146.52 581034 0,~ 0.~ 0,~ 157.~ 49~.7~ ~[.~ ~55.77 50,70 50.21 35.5g M~ B~ 91~.33 ~.6~ 160,82 ~28.~ ~,~ 58.78 4866.~ S 3212.7~ E ~2~6.51 561~62 583~.9~ 14~.57 5830.51 0.~ 0.~ 0.~ 157.~ 4978.36 g ~ E 256A1 50,~ 50.~ 35.~ M~ MK-19 TZUD ~392,22 ~.66 160.~ ~9.(~ 6697.~ 81.22 4948.298 3241.35E 6~3~4.47 561~i.91 5915.40~146.77 5915.19 0.~ 0,~ 0.~ 157.2 5~.93 $ ~l~B 259.11 51.~ 50.~ 36.15 Mi~ 'TK~ 94~.42 ~.6~ 1~.82 6~1,~ 672~.~ 34,20 ~959.~S ~245.32E 6~3~.11 561~5.~ 5~.11~146.80 592~,~ 0.~ 0.~ 0.~ 157.2 5~7~ 311~.~ 25P.~8 52,08 50.5t 3~,21 M~ T~g~ I TK~ 9595.28 ~.66 1~.82 6~9.~ ~87.~ 168.86 5015.97 S 32~.~ E 60238~.~ 561716.~ 59~.~4~ 146.94 5984.85 0.~ 0.~ 0.~ 157.~ 51~.84 ~ ~1~.10~ 261.33 52.~ 50.~ ~.5~ M~ TKU~ ~.07 ~.6~ 1~.82 d~75.~ ~13,~ 27.79 5~5.~ 3268.12E ~38d7.77 561719.~ 5g~.4~146.9~ 5~4.38 0.~ 0.~ 0.~ 157.2 51~8.1~ S 3131~E 2~1.6~ 52,~ 50,~ 3~8 M~ TKUA 1 Sunt~i,, Tool Halliburton Energy Services - Drilling Systems PSL Proposal Report Page2 Date: 1214/95 Wellp~llt ID: MPC-22AWp2 Measured Iflcl Drift Sub~a 7'VD Co~ T 0 T A L Depth Dh'. l)epth Leaph Rectangular Off~ (a) (~g.) (~g.) (tO (n) (a) (fO GRID Coo.,'ffma les (n) CIo~m Ve~lical Build Walk DIS ~ Expe~ed Tolal Max Hot MIa l/or Dit. Ve~t Di~l. Dff. $ectitm Rate Rzle D~gleg Rr. ctaagular Coords E~oe Er~0~ Max ~r (n) (c~g.) (n) (dg/~OOe) (dgnOOn) (Ug/~OOe) (&-g) (fl) in) (et) (n) (ueg,) 9689.33 20,66 160,82 6937.00 6975.00 66.26 5047.31 $ 3275.g0E 6023845.75 561'/27.16 6017.16@147.02 6017,11 0.00 0.00 0.00 157.2 5160.308 3139,68E 262.36 53.16 50.73 36.70 MWD TMLV 9694.67 20,66 160,82 6942.00 6980.00 5.34 5049.105 3276.42E 6023843,98 561727.79 60t8.99~14'/.02 6018.94 0.00 0.00 0.00 157.2 5162.085 3140,29E 262,42 53,18 50.74 36.71 MWD 9994.67 20,66 160,82 7222.70 7260.70 300_00 5149.088 3311.201~ 6023744.30 561763.3~) 6121.85~149.26 6121,85 0.00 0.00 0.00 157.2 5262425 3174,05E 265,72 54,41 50.99 37.27 MWD Survey Tool T~EF_: 3 1/8'-5M CAMERON WELLHEAD: 13-5/8' 5M FMC UNIVERSAL SLIM HOLE w/3.5' FMC Tubing Hanger and 3-1/2' 'H' BPV profile 1' 20' 94#/I! H-40 BIS 112' MP C-22 PROPO£' ~--"-',~ WELLBORE SCHEMATIC ORIG. KB. ELEV = 46' (Nat)om 22~. IRIG. GL ELEV = 26' (Nat)om 22E) 0-3/4' CASING HANGER CROSSED OVER TO 9-5/8' BTS CASING '-5/8' CASING HANGER CROSSED OVER TO 7' MOD BTS CASING KOP = 500' MAX HOLE Angle = 55.06* @ 28001VlD #2 ESP POWER CABLE 2°7/8' 6.5#, L-80 EUE 8RD 2.441' ID, 2.347' DRIFT CAPACI'r'Y: 0.00579 BBL/FT . L-80 Csg. Liner CENTRILIFT ESP TANDEM SEALS CENTRILIFT MOTOR CENTRILIFT PHD @+/-8350' ?? Approx. 50' above the window. Cement Retainer @ 8583' MD (161 sks of Class 'G" was squeezed below retainer) 2-7/8' GLM w/SHEAR VALVE SHEAR SET > 3500 DELTA P CENTRILIFT CHECK VALVE CENTRILIFT ESP TANDEM SEALS CENTRILIFT MOTOR CENTRILIFT PHD 8,734' 8,761' 8,857' 8,864' 8,877' 8,892' 8,945' 7' BAKER FB-1 PACKERW/ I I 22' 20 GA, SCREEN AND TP 3-1/2' XN NIPPLE w/PXN I I PLUG (2.75' ID) 8,972' ~ +/-2oo' ~ PBTD I 9,932' 5' 15#, 13Cr-80, FL4S [ 10,063' DATE REV. BY - COMMENTS 11/1/94 DH PROPOSED WORKOVER COMPLETION 12/31/94 JBF ACTUAL COMPLETION 12/31/94 3/14~5 RBF Proposed Sidetrack Completion MILNE POINT UNIT WELL C-22 APl NO: 50-029-22489 BP EXPLORATION (AK) ~LC'~orv"~ U~L ~INIJ LiA,.5 L;r.3NSEFIVATION CO SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend., Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging X Time extension Stimulate __ Change approved program Pull tubing__" Variance. Perforate__ Other X ~ Plugback for Reddll 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 582' NSL, 2054' WEL, SEC. 10, T13N, RIOE At top of productive interval 894' NSL, 1443' EWL, SEC. 14, T13N, RIOE At effective depth At total depth 769' NSL, 1558' EWL, SEC. 14, T13N, RIOE 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 45.95' feet 7. Unit or Property name MI/ne Point Unit 8. Well number MPC-22 9. Permit number 94-89 10. APl number 5O- O29-22489 11. Field/Pool Mi/ne Point-Kuparuk Sands 12. Present well condition summary Total depth: measured true vertical 10065 7284 feet Plugs (measured) Please see attached diagram feet .... Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 8583 feet Junk (measured) 5970 feet Length Size Cemented Please see attached diagram Measured depth True vertical depth 80' 20" 250 sx AS (approx.) 6685' 9-5/8' 1300 sx PF "E'/250 sx "G" 1 I2' 112' 6715' 4758' 9226' 7" 150 sx Class 'G" 9253' 1014' 5" 120 sx Class 'G' 9050'10064' measured 9644'-9726', 9582'9586', 9558'-9564', 9472'-9478'(squeezed off) 6540' 6354'7284' true vertical 6898'6973', 6841'6845', 6819'6825', 674,'6746'(squeezed off) RECEIVED Tubing (size, grade, and measured depth) 2-7/8', L-80 Tubing to 8400' MD Packers and SSSV (type and measured depth) Stuck ESP assembly @ 8764' MD 13. Attachments Description summary of proposal ~ Detailed operations program 14. Estimated date for commencing operation 12/10/95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended X Service 17. ! hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title o....~.., r,..,,,,.~- ~--:~--- FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity v BOP Test ~ Location clearance --/-/o 7 Mechanical Integrity~t~, ~ ~ ~~..~ j ~ '~------~__ Form_ 10-403 Rev 06/15/88 ~~ ~ _ I Approval No. Date SUBMIT I¢~ TI~IPLICATE vv LL PERMIT CHECKLIST PROGRAM: exp [] .17.? dev [] redrll~ serv [] ON/OFF SNORE ~ ADMINISTRATION APPR DA~E . 1. 2. 3. 4. £ Permit fee attached .................. ~Y Lease number.appropriate ............... Y Unique well name and number .............. Y Well located in a defined pool .............. Y Well located proper distance from drlg unit boundary...Y 5. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... Y Y Y .Y .Y Y .Y Y ENGINEERING REMARKS 14. Conductor string provided ................ 15. Surface casing protects all known USDWs ......... 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26. BOPE press rating adequate; test to psig.~3_) 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... 29. Is presence of ~2S gas probable ............ GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures .... Y ~/ 31. Data presented on potential overpressure zones ..... Y/N 32. Seismic analysis of shallow gas zones ......... / N 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . ...~ . . Y N [exploratory only] 44 GEOLOGY: · ENGINEERING: COMMI SS ION: JDH ~ JDN Comments/Instructions: '~WIIjb - A:~FORMS~cheklist rev 11195 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. ' No special effort has been made to chronologically organize this category of information. MPC - 22A MILNE POINT 0 ~ '.~ ~:.~,- -- --- - ' ---~; .:~...-. ---~:;_, -- :--::.: .. ---;:,:_.: · :........ .:, .. .,. . '.. ,~;.-] - .~- --- ...... t . --;-_:....'- ::.-'.": .:-.: - ~ ~ 8430 . , , .: '~ ,: . % ~.. , .. Run 1' 23 - December - t995 DIFL/GR 9982 Date .... ATLAS Logging Services _ape Subfile 2 is type.f-LiS ~=- TAPE HEADER , , MILNE POINT UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: RUN 1 6553.00 BRAD ESARY M. FERNANDEZ MPC - 22A 500292248901 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 03 -JAN- 96 RUN 2 RUN 3 10 13N 10E 582 2054 46.00 .00 17.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 8435.0 6.000 9995.0 DIFL/GR. CIRCULATION STOPPED @ 08:30, 23-DEC-95. ALL DEPTH REFERENCES ARE ORIGINAL R.K.B. NABORS 22E = 46' ABOVE M.S.L. THIS WELL DRILLED BY NABORS 4ES WITH R.K.B. = 48' ABOVE M.S.L. CHLORIDES: 700 MG/L. GAMMA RAY AFTER LOG VERIFICATION NOT WITHIN SPECIFICATION, +/- 10 API. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (6.000"). THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. FILE HEADER FILE NUMBER: , · 1 EDITED OPEN HOLE MAIN PASS All tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE START DEPTH GR - 8430.0 DIL 8430.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) depth shifted and clipped curves; .5000 STOP DEPTH 9956.0 9982.0 BASELINE DEPTH LL8 8522.5 8522.0 8531.5 8531.5 8658.5 8658.5 8698.0 8698.0 8707.0 8707.0 8713.5 8713.5 8719.5 8720.0 8734.0 8734.0 8802.5 8802.5 8804.0 8804.5 8835.0 8835.0 8869,5 8869.5 8937.0 8940.0 8957.0 8957.5 8998.0 8998.5 9000.5 9000.5 9008.0 9008.0 9115.5 9115.5 9170.0 9170.0 9198.5 9198.5 9222.0 9222.0 9254.0 9254.0 9256.0 9276.5 9276.5 9335.5 9335.5 9348.5 9348.5 9360.0 9360.5 9365.5 9365.0 9370.0 9370.0 9397.0 9396.5 9404.5 9404.5 9411.5 9411.5 9416 . 5 9416 . 0 9419.0 9424 . 5 9424 . 5 9447.0 9447.5 9468.5 9468.0 9490 . 0 9489 . 5 9515.5 9515.5 9517.5 9517.5 9522.0 9522.0 all EQUIVALENT UNSHIFTED DEPTH ILD 8522.0 8531.5 8658.5 8697.5 8707.0 8713.5 8720.0 8734.0 8802.5 8804.5 8835.0 8869.5 8937.0 8941.0 8957.5 8998.5 9000.5 9008.0 9115.5 9170.0 9198.5 9222.0 9256.5 9276.5 9335.5 9348.5 9360.5 9365.0 9370.0 9396.5 9404.5 9411.5 9419.0 9425.5 9447.5 9468.0 9489.5 9515.5 9517.5 9522.0 runs merged; no case 9538.5 9578.5 9591.5 9607.5 9616.5 9621.5 9623.5 9627.5 9633.0 9651.5 9659.0 9666.5 9671.5 9696.0 9714.0 9720.5 9807.5 9839.5 9872.0 9877.5 9913.0 $ MERGED DATA SOURCE PBU TOOL CODE GR DIL $ REMARKS: 9~.9.0 9538.5 5 ~.5 9578.5 9591.0 9607.5 9607.5 9616.0 9621.0 9621.0 9623.5 9627.0 9627.0 9633.0 9633.0 9651.5 9651.5 9659.0 9659.0 9666.5 9666.5 9671.5 9671.5 9696.0 9696.0 9714 . 0 9714 . 0 9721.0 9807.5 9807.5 9839.5 9839.5 9871.5 9871.5 9877.5 9877.5 9913.0 9913.0 RUN NO. PASS NO. MERGE TOP 1 2 8430.0 1 2 8430.0 OPEN HOLE portion of MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH LLD. MERGE BASE 9956.0 9982.0 CN WN FN COUN STAT /? ?MATCH1. OUT / ? ?MATCH2. OUT $ : BP EXPLORATION (ALASKA) : MPC-22A : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units 1 GR DIL 68 2 LL8 DIL 68 3 ILM DIL 68 4 ILD DIL 68 1 GAPI 1 OHMM 1 OHMM 1 OPIMM Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 08 310 01 1 4 08 995 99 1 4 08 995 99 1 4 08 995 99 1 5 RT DIL 6?~ 1 OHMM 4 6 DI DIL 6~ 1 IN 4 7 SP ~IL ~ 68 1 MV 4 8 MTEM DIL 68 1 DEGF 4 9 TEND DIL 68 1 LB 4 10 TENS DIL 68 1 LB 4 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 139 08 995 99 ~ 08 995 99 4 O8 995 99 4 O8 995 99 4 08 995 99 4 08 995 99 40 Tape File Start Depth = 10007.000000 Tape File End Depth = 8415.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35036 datums Tape Subfile: 2 299 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes .. Tape Subfile 3 is type: ~IS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 presented first (primary depth control string used for depth shifting) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8422.5 DIFL 8422.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR) : STOP DEPTH 9971.0 9997.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR KNJT DIFL $ CABLEHEAD TENS ION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY KNUCKLE JOINT DUAL INDUCTION BOREHOLE AND' CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT) : BOREHOLE COND I T IONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: 23-DEC-95 FSYS REV. J001 VER. 1.1 830 23-DEC-95 1955 23-DEC-95 9995.0 9985.0 8430.0 9982.0 2100.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 3921NA 1503XA 6.000 8435.0 8430.0 LSND 11.40 56.0 9.8 10.8 154.4 .560 .280 .400 .000 .680 74.7 154.4 74.7 .0 74.7 MUD CAKE AT B~ ]00 .0 NEUTRON TOOL ' TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC-22A : MILNE POINT/KUPARUK : NORTH SLOPE .00 .000 .5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 2 RFOC DIFL 68 1 OFIMM 4 3 RILM DIFL 68 1 OHMM 4 4 RILD DIFL 68 1 OHMM 4 5 CFOC DIFL 68 1 MMHO 4 6 CILM DIFL 68 1 MMHO 4 7 CILD DIFL 68 1 MMHO 4 8 VILM DIFL 68 1 MV 4 9 VILD DIFL 68 1 MV 4 10 RT DIFL 68 1 OHMM 4 11 DI DIFL 68 1 IN 4 12 SP DIFL 68 1 MV 4 13 TEMP DIFL 68 1 DEGF 4 14 CHT DIFL 68 1 LB 4 15 TTEN DIFL 68 1 LB 4 16 SPD DIFL 68 1 F/MN 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 210 06 1 4 07 110 44 1 4 07 110 46 1 4 07 995 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 455 Tape File Start Depth = 10007.000000 Tape File End Depth = 8415.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **~, LIS represent~tion~code decoding summary: Rep Code: 68 108274 datums Tape Subfile: 3 529 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type~ alS FILE HEkDER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9546.0 DIFL 9546.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 9971.0 9997.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MIS TEMP PCM GR KNJT DIFL $ CABLEHEAD TENSION MASS ISOLATION SUB TEMPERATURE PULSE CODE MODULATOR GAMMA RAY KNUCKLE JOINT DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 23-DEC-95 FSYS REV. J001 VER. 1.1 830 23-DEC-95 1905 23-DEC-95 9995.0 9985.0 8430.0 9982.0 2100.0 TOOL NUMBER 3974XA 3967XA 2806XA 3506XA 1309XA 3921NA 1503XA 6.000 8435.0 8430.0 LSND 11.40 56.0 9.8 10.8 154.4 .560 .280 .400 .000 .680 .000 74.7 154.4 74.7 .0 74.7 .0 NEUTRON TOOL TOOL TYPE (E?ITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ --' CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC-22A : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .00 .000 .5 * FORMAT RECORD (TYPE# 64) . ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 2 RFOC DIFL 68 1 OHMM 4 3 RILM DIFL 68 1 OHMM 4 4 RILD DIFL 68 1 OHMM 4 5 CFOC DIFL 68 1 MMHO 4 6 CILM DIFL 68 1 MMHO 4 7 CILD DIFL 68 1 MMHO 4 8 VILM DIFL 68 1 MV 4 9 VILD DIFL 68 1 MV 4 10 RT DIFL 68 1 OHMM 4 11 DI DIFL 68 1 IN 4 12 SP DIFL 68 1 MV 4 13 TEMP DIFL 68 1 DEGF 4 14 CHT DIFL 68 1 LB 4 15 TTEN DIFL 68 1 LB 4 16 SPD DIFL 68 1 F/MN 4 4 07 310 01 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 210 06 1 4 07 110 44 1 4 07 110 46 1 4 07 995 46 1 4 07 995 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 660 99 1 4 07 635 99 1 4 07 635 99 1 4 07 636 99 1 64 DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 133 Tape File Start Depth = 10007.000000 Tape File End Depth = 9543.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation cod~ ~ecoding summary: Rep Code: 68 66606 datums Tape Subfile: 4 206 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: ~IS O1 **** REEL TRAILER **** 96/ 1/ 3 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 3 JAN 96 1:29p Elapsed execution time = 2.80 seconds. SYSTEM RETURN CODE = 0
